Wireline and Perforating Products and Services Catalog - Halliburton
Wireline and Perforating Products and Services Catalog - Halliburton
Wireline and Perforating Products and Services Catalog - Halliburton
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Knowledge <strong>and</strong> Data Transfer<br />
Reservoir Evaluation <strong>Services</strong><br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
<strong>Perforating</strong> Solutions<br />
Downhole Video<br />
Slic Slickline Service Equipment <strong>and</strong> <strong>Services</strong><br />
Mobilization<br />
Mnemonics
Table of Contents<br />
Knowledge <strong>and</strong> Data Transfer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-1<br />
Real-Time Operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-1<br />
Real-Time Data/Solution Delivery. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-1<br />
HalLink ® Satellite Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-2<br />
InSite Anywhere ® Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-3<br />
Reservoir Evaluation <strong>Services</strong> . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-1<br />
Petrophysics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-1<br />
MRI Petrophysics. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-1<br />
MRIL ® Simultaneous T 1 <strong>and</strong> T 2 Measurements . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-1<br />
MRIAN Magnetic Resonance Imaging Analysis. . . . . . . . . . . . . . . . . . . . . . . . . .2-2<br />
Time Domain Analysis (TDA). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-4<br />
Diffusion Analysis (DIFAN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-5<br />
Enhanced Diffusion Method (EDM) Technique . . . . . . . . . . . . . . . . . . . . . . . .2-6<br />
Heavy Oil MRIAN SM Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-7<br />
StiMRIL Process . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-8<br />
Volumetric Petrophysics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-10<br />
Chi Modeling ® Computation Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-10<br />
ULTRA Module Suite . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-12<br />
SASHA Shaly S<strong>and</strong> Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-14<br />
CORAL Complex Lithology Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-15<br />
LARA Laminated Reservoir Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-16<br />
Reservoir Characterization. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-17<br />
Borehole Image Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-17<br />
AutoDip <strong>and</strong> TrendSetter <strong>Services</strong>. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-17<br />
AutoDip Service. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-18<br />
TrendSetter Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-18<br />
ReadyView Open-Hole Imaging System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-20<br />
Facies Profile . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-22<br />
Net2Gross S<strong>and</strong> Count . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-24<br />
ImagePerm . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-25<br />
Borehole Geophysics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-26<br />
Wellbore Seismic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-26<br />
High Resolution Seismic Imaging—(Near Offset VSP, Fixed Offset VSP,<br />
Walkaways, 3D VSP, Salt Proximity Surveys, Microseismic Surveys) . . . . . . . . .2-26<br />
Reservoir Geophysics. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-27<br />
Long Array Multi-Component Acquisition Tools . . . . . . . . . . . . . . . . . . . . . . . . . .2-27<br />
GeoChain VSP Downhole Receiver Array . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-27<br />
Synthetic Seismic <strong>and</strong> Sonic Log Calibration . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-27<br />
Vertical Incidence Vertical Seismic Profiling (VIVSP) Analysis . . . . . . . . . . . . . .2-28<br />
ExactFrac ® <strong>Services</strong>. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-29<br />
Acoustics <strong>and</strong> Rock Properties. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-30<br />
Table of Contents i
Anisotropy Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-30<br />
RockXpert2 Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-32<br />
FracXpert Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-34<br />
AcidXpert Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-36<br />
Reservoir <strong>and</strong> Production Engineering . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-38<br />
Reservoir Testing Studio . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-38<br />
RTS Reservoir Testing Studio . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-38<br />
Pressure Time Plot . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-38<br />
Exact Buildup Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-39<br />
Exact Anisotropy Analysis Plot . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-39<br />
FasTest ® Buildup Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-40<br />
Horner Time Plots . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-40<br />
Log-Log Derivative Analysis Plot . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-41<br />
PVT Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-42<br />
Formation Test Summary Program (FTS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-42<br />
Well Testing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-44<br />
Well Test Design . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-44<br />
Well Test Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-46<br />
Multi-Layered Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-47<br />
Reservoir Evaluation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-48<br />
SigmaSat Model . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-48<br />
CarbOxSat Model. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-49<br />
TripleSat Model . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-50<br />
Production Logging Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-51<br />
Production Logging Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-51<br />
FloImager ® Analysis Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-54<br />
FloImager ® 3D Software Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-54<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-1<br />
Resistivity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-1<br />
ACRt Array Compensated Resistivity Tool System . . . . . . . . . . . . . . . . . . . . . . . . . .3-1<br />
HRAI High Resolution Array Induction Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-3<br />
HRI High Resolution Induction Tool. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-4<br />
HDIL Hostile Dual Induction Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-5<br />
DLL Dual Laterolog Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-6<br />
MSFL Micro-Spherically Focused Log <strong>and</strong> Microlog (ML) . . . . . . . . . . . . . . . . . . . .3-7<br />
HFDT High Frequency Dielectric Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-8<br />
Imaging. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-9<br />
EMI Electrical Micro Imaging Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-9<br />
XRMI X-Tended Range Micro Imager Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-11<br />
OMRI Oil-Based Micro-Imager Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-13<br />
CAST-V Circumferential Acoustic Scanning Tool-Visualization. . . . . . . . . . . . . . .3-15<br />
SED Six Arm Dipmeter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-16<br />
Nuclear . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-17<br />
SDL Spectral Density Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-17<br />
ii Table of Contents
DSN Dual-Spaced Neutron Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-19<br />
DSEN Dual-Spaced Epithermal Neutron Log Tool . . . . . . . . . . . . . . . . . . . . . . . . . .3-21<br />
CSNG Compensated Spectral Natural Gamma Ray . . . . . . . . . . . . . . . . . . . . . . . . .3-22<br />
Acoustics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-24<br />
BSAT Borehole Compensated Sonic Array Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-24<br />
WaveSonic ® Tool. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-25<br />
FWS Full Wave Sonic Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-27<br />
NMR. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-29<br />
MRIL-XL <strong>and</strong> MRIL ® -Prime Magnetic Resonance Image Logging Tools . . . . . . .3-29<br />
MRILab ® Magnetic Resonance Image Fluid Analyzer . . . . . . . . . . . . . . . . . . . . . . . . .3-31<br />
Borehole Geophysics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-33<br />
Wellbore Seismic . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-33<br />
High Resolution Seismic Imaging—(Near Offset VSP, Fixed Offset VSP,<br />
Walkaways, 3D VSP, Salt Proximity Surveys, Microseismic Surveys) . . . . . . . . .3-33<br />
Reservoir Geophysics. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-34<br />
Long Array Multi-Component Acquisition Tools . . . . . . . . . . . . . . . . . . . . . . . . . .3-34<br />
GeoChain VSP Downhole Receiver Array . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-34<br />
Synthetic Seismic <strong>and</strong> Sonic Log Calibration . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-34<br />
Vertical Incidence Vertical Seismic Profiling (VIVSP) Analysis . . . . . . . . . . . . . .3-35<br />
ExactFrac ® <strong>Services</strong>. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-36<br />
Sampling. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-37<br />
RDT Reservoir Description Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-37<br />
DPS Dual Probe Section . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-39<br />
Oval Pad . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-39<br />
Straddle Packer. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-39<br />
FPS Flow-Control Pump-Out Section . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-39<br />
QGS Quartz Gauge Section . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-39<br />
MRILab Section . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-40<br />
MCS Multi Chamber Section. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-40<br />
CVS Chamber Valve Section. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-40<br />
SFT-IV Sequential Formation Tester IV Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-41<br />
SFTT Sequential Formation Test Tool. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-42<br />
RSCT Rotary Sidewall Coring Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-43<br />
SWC Side Wall Coring Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-45<br />
HRSCT Hostile Rotary Side Wall Coring Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-46<br />
Hydraulic Valve Section . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-46<br />
Motor Drive Section. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-46<br />
M<strong>and</strong>rel Section . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-46<br />
Hostile—Slimhole Formation Evaluation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-47<br />
HEAT Hostile Environment Applications Tool Suite . . . . . . . . . . . . . . . . . . . . . . . .3-47<br />
HEDL Hostile Environment Dual Laterolog Tool . . . . . . . . . . . . . . . . . . . . . . . .3-48<br />
HFWS Hostile Full Wave Sonic Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-49<br />
HSDL Hostile Spectral Density Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-51<br />
HDSN Hostile Dual-Spaced Neutron Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-53<br />
Table of Contents iii
HNGR Hostile Natural Gamma Ray Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-55<br />
HSFT Hostile Sequential Formation Tester Tool. . . . . . . . . . . . . . . . . . . . . . . . .3-56<br />
Auxiliary <strong>Services</strong> . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-57<br />
Multi-Conductor LockJar ®* System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-57<br />
Borehole Conditions. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-58<br />
RWCH Releaseable <strong>Wireline</strong> Cable Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-59<br />
Toolpusher Logging (TPL) Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-60<br />
CTL Coiled Tubing Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-62<br />
BHPT Borehole Properties Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-63<br />
FIAC Four Independent Arm Caliper Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-65<br />
SDDT St<strong>and</strong>-Alone DITS Directional Tool. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-67<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-1<br />
Formation Evaluation. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-1<br />
TMD-L Thermal Multigate Decay-Lithology Logging Tool. . . . . . . . . . . . . . . . . . . .4-1<br />
RMT Elite Reservoir Monitor Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-3<br />
Spectra Flow Logging Service (SpFl) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-5<br />
DSN Dual-Spaced Neutron Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-7<br />
FCMT Formation Compaction Monitoring Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-9<br />
CASE Casing Evaluation <strong>and</strong> Inspection Software . . . . . . . . . . . . . . . . . . . . . . . . . .4-10<br />
Through Casing Acoustic <strong>Services</strong> . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-12<br />
WaveSonic ® Tool. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-12<br />
FWS Full Wave Sonic Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-14<br />
HFWS Hostile Full Wave Sonic Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-16<br />
Production Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-18<br />
Production Logging Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-18<br />
Memory Production Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-18<br />
Electric Line Production Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-18<br />
FloImager ® Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-21<br />
GHT Gas Holdup Tool. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-23<br />
MPL Memory Production Logging Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-24<br />
Quartz Pressure Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-27<br />
Casing <strong>and</strong> Tubing Evaluation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-28<br />
MAC Multi-Arm Caliper Tool. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-28<br />
CAST-V Circumferential Acoustic Scanning Tool-Visualization. . . . . . . . . . . . . . .4-29<br />
The FASTCAST Fast Circumferential Acoustic Scanning Tool . . . . . . . . . . . . . . . .4-31<br />
Cement Evaluation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-33<br />
Cement Bond Log (CBL). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-33<br />
Radial Cement Bond Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-35<br />
ACE Advanced Cement Evaluation Process . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-37<br />
Mechanical <strong>Services</strong>. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-39<br />
Pipe Recovery . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-39<br />
Chemical Cutter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-39<br />
Tubing Cutters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-42<br />
*LockJar is a registered trademark of Evans Engineering, Inc.<br />
iv Table of Contents
Super Tubing Cutters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-44<br />
Coiled Tubing Cutters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-46<br />
Casing <strong>and</strong> Drillpipe Cutters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-48<br />
C-4 Casing Cutters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-50<br />
Drill Collar Severing Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-51<br />
Junk Shot . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-53<br />
Plug Setting Equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-54<br />
EZ Drill ® Bridge Plugs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-54<br />
Fas Drill ® Bridge Plugs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-55<br />
<strong>Perforating</strong> Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-1<br />
Shaped Charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-1<br />
MaxForce Shaped Charges. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-1<br />
Dominator ® Shaped Charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-2<br />
Mirage ® Shaped Charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-3<br />
Maxim Shaped Charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-5<br />
KISS Low-Damage <strong>Perforating</strong> Charge. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-6<br />
Gun Systems. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-10<br />
VannGun ® Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-10<br />
1 9/16 in. to 7 in. <strong>and</strong> 4 SPF to 21 SPF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-10<br />
VannGun Phasing <strong>and</strong> Shot Patterns . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-11<br />
0° Phasing 4 <strong>and</strong> 5 SPF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-11<br />
60° Phasing 4, 5, <strong>and</strong> 6 SPF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-11<br />
90° Phasing 4 SPF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-12<br />
180° Phasing 4 <strong>and</strong> 8 SPF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-12<br />
60° Phasing 6 SPF Two Planes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-13<br />
45°/135° Phasing 5, 6, 8, 12, <strong>and</strong> 18 SPF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-13<br />
140°/160° Phasing 11 SPF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-14<br />
51.4°/154.3° Phasing 12 SPF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-14<br />
30°/150° Phasing 12 SPF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-14<br />
25.7°/128.5° Phasing 14 SPF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-15<br />
60°/120° Phasing 18 <strong>and</strong> 21 SPF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-15<br />
138° Phasing 14 SPF . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-15<br />
Tensile Ratings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-16<br />
1 9/16-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-16<br />
2-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-17<br />
2 1/2-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-18<br />
2 3/4-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-19<br />
2 7/8-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-20<br />
3 3/8-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-21<br />
4-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-23<br />
4 1/2-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-24<br />
4 5/8-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-25<br />
4 3/4-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-28<br />
5-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-29<br />
Table of Contents v
5 1/8-in. Premium VannGun ® Assemblies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-31<br />
5 3/4-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-33<br />
6-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-33<br />
6 1/2-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-34<br />
6 1/2-in. High-Pressure Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . .5-35<br />
7-in. Premium VannGun Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-36<br />
Capsule Gun Systems. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-41<br />
Dyna-Star ® Capsule Gun . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-41<br />
Deep Star Capsule Gun . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-42<br />
1.6875-in. <strong>and</strong> 2.125-in. Deep Star Debris Fill Data . . . . . . . . . . . . . . . . . . . . . . . .5-43<br />
Ported Gun <strong>Perforating</strong> System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-44<br />
Firing Heads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-45<br />
Detonation Interruption Device . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-45<br />
Mechanical Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-46<br />
Model II-D Mechanical Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-47<br />
Model III-D Mechanical Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-48<br />
Pressure-Actuated Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-49<br />
Model K <strong>and</strong> K-II Firing Heads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-50<br />
Model KV-II Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-51<br />
Time-Delay Firer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-52<br />
Multiaction-Delay Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-53<br />
Annulus Pressure Firer-Control Line . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-54<br />
Annulus Pressure Transfer Reservoir. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-55<br />
Slimhole Annulus Pressure Firer—Internal Control . . . . . . . . . . . . . . . . . . . . . . . . . . .5-56<br />
5-in. Annulus Pressure Transfer Reservoir . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-56<br />
3 1/8-in. Internal Control . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-56<br />
3 1/8-in. Annulus Pressure Transfer Reservoir—Internal Control . . . . . . . . . . . . . . . .5-56<br />
Differential Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-57<br />
Hydraulic Actuator Firing Head <strong>and</strong> Swivel-Type Hydraulic Actuator<br />
Firing Head. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-58<br />
Mechanical Metering Hydraulic-Delay Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . .5-59<br />
Slickline-Retrievable Mechanical Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-60<br />
Slickline-Retrievable Time-Delay Firer Firing Head. . . . . . . . . . . . . . . . . . . . . . . . . . .5-62<br />
Extended Delay Fuses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-63<br />
Modular Mechanical Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-64<br />
Side-Pocket M<strong>and</strong>rel Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-66<br />
Annulus Pressure Crossover Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-67<br />
EZ Cycle Multi-Pressure Cycle Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-68<br />
Pump-Through Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-70<br />
Ancillary Equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-71<br />
Fill Disk Assembly. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-71<br />
Balanced Isolation Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-72<br />
Ratchet Gun Connector . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-74<br />
AutoLatch Release Gun Connector . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-75<br />
vi Table of Contents
Isolation Sub-Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-76<br />
Quick Torque Connector . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-77<br />
Detach Separating Gun Connector. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-79<br />
Rathole Length Restriction. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-79<br />
Rigless Completion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-79<br />
EZ Pass Gun Hanger . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-80<br />
Automatic-Release Gun Hanger—Rotational Set . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-82<br />
Automatic-Release Gun Hanger—Automatic-J M<strong>and</strong>rel . . . . . . . . . . . . . . . . . . . . . . .5-84<br />
Explosive Transfer Swivel Sub . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-86<br />
Shearable Safety Sub . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-87<br />
Roller T<strong>and</strong>em Assembly. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-88<br />
Centralizer T<strong>and</strong>em . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-89<br />
Emergency Release Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-90<br />
Annular Pressure-Control Line Vent . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-91<br />
Annular Pressure-Control Line Swivel Sub . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-92<br />
Annular Pressure-Control Line Tubing Release . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-93<br />
Bar Pressure Vent. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-94<br />
Below-Packer Vent Device . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-95<br />
Maximum Differential Bar Vent . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-96<br />
Pressure-Operated Vent . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-97<br />
Vann Circulating Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-98<br />
Automatic Release . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-99<br />
Mechanical Tubing Release . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-101<br />
Pressure-Actuated Tubing Release. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-103<br />
DPU ® Downhole Power Unit. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-104<br />
SmartETD ® Advanced Electronic Triggering Device . . . . . . . . . . . . . . . . . . . . . . . . .5-105<br />
Y-Block Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-106<br />
Non-Ported . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-106<br />
Ported . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-106<br />
Gun Guides. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-107<br />
Hydraulic Metering Release Tool for the Single Trip System<br />
(STPP-GH) Tool. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-108<br />
Fast Gauge Recorder . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-110<br />
Gamma Perforator Logging Tool. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-112<br />
Detonators . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-113<br />
Capsule RED ® Detonators . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-113<br />
RED GO-Style Thermal Igniter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-114<br />
Block RED Detonators. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-115<br />
Top Fire RED Detonators . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-116<br />
Dynamic Modeling. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-117<br />
PerfPro ® Process . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-117<br />
PerfPro Process–Predicting In-Situ Charge Performance . . . . . . . . . . . . . . . . . . .5-117<br />
Near-Wellbore Stimulation <strong>and</strong> PulsFrac Software . . . . . . . . . . . . . . . . . . . . . . . . .5-120<br />
EOB - Energized Fluid Stimulation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-120<br />
Table of Contents vii
Propellant Stimulation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-121<br />
ShockPro SM Shockload Evaluation Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-125<br />
Near-Wellbore Stimulation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-127<br />
StimGun* Assembly. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-127<br />
Propellent Stimulation Tool Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-130<br />
POWR*PERF SM Perforation/Stimulation Process. . . . . . . . . . . . . . . . . . . . . . . . . . . .5-132<br />
PerfStim Process. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-133<br />
Oriented <strong>Perforating</strong>. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-134<br />
G-Force ® Precision Oriented <strong>Perforating</strong> System . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-134<br />
Oriented <strong>Perforating</strong> with Modular Guns. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-136<br />
Finned Orienting T<strong>and</strong>em . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-137<br />
Eccentric Orienting T<strong>and</strong>em . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-138<br />
Special Applications. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-139<br />
Modular Gun System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-139<br />
The Modular Gun System Process . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-140<br />
Rathole Length Restriction. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-140<br />
Rigless Completion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-140<br />
Select Fire Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-141<br />
Coiled Tubing Conveyed <strong>Perforating</strong> . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-142<br />
DrillGun <strong>Perforating</strong> Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-143<br />
Setting Tools for the Auto-Release Gun Hanger . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-145<br />
Running <strong>and</strong> Retrieving Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-145<br />
Downhole Video . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-1<br />
Downhole Video <strong>Services</strong> . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-1<br />
Hawkeye Camera System. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-2<br />
Fiber-Optic Camera System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-3<br />
EyeDeal Camera System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-4<br />
Slickline Service Equipment <strong>and</strong> <strong>Services</strong> . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-1<br />
Subsurface Service Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-2<br />
Slickline Service Tools. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-2<br />
Slickline Toolstring . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-2<br />
Otis ® Accelerators . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-3<br />
Slickline Detent Jars. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-4<br />
Otis Quick Connect Toolstring Connection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-5<br />
Auxiliary Tools For Use with Slickline Toolstring . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-6<br />
Otis Gauge Cutter <strong>and</strong> Swaging Tools. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-6<br />
Otis Impression Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-6<br />
Otis Tubing Broach . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-6<br />
Otis M Magnetic Fishing Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-6<br />
Otis G Fishing Socket . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-7<br />
Otis P <strong>Wireline</strong> Grab . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-7<br />
*StimGun is a trademark of Marathon Oil Company.<br />
viii Table of Contents
Otis ® Go-Devil. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-7<br />
Exp<strong>and</strong>able Wirefinder . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-7<br />
Running Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-8<br />
Otis X ® <strong>and</strong> R ® Running Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-8<br />
Otis RXN Running Tools. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-8<br />
Otis UP Running Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-8<br />
Otis MR Running Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-8<br />
Pulling Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-9<br />
Internal Fishing Necks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-9<br />
External Fishing Necks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-9<br />
Test Tools. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-11<br />
Otis Non-Selective Test Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-11<br />
Positioning Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-12<br />
Tubing Perforators <strong>and</strong> Bailers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-13<br />
Slickline Skid Units <strong>and</strong> Trucks. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-14<br />
Surface Service Equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-15<br />
Advanced ® Slickline <strong>Services</strong> . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-16<br />
Advanced Slickline Service System. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-18<br />
DPU ® Tubing Punch . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-22<br />
CollarTrak ® Slickline Collar Locator . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-23<br />
Advanced Measurement System (AMS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-25<br />
Electronic Advanced Measurement System (Portable) . . . . . . . . . . . . . . . . . . . . . . . . .7-26<br />
SmartETD ® System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-27<br />
JobTrak ® Data Job Logger. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-28<br />
St<strong>and</strong>ard Mounted Equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-28<br />
Memory Production Logging (MPL) Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-29<br />
LineTrak ® Slickline Inspection Device <strong>and</strong> Wire Management Program . . . . . . . . . . .7-31<br />
Wire Management Program . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-31<br />
Deepwater Riserless Subsea Light Well Intervention System . . . . . . . . . . . . . . . . . . . .7-33<br />
Mobilization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-1<br />
LOGIQ Logging Truck . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-1<br />
LOGIQ Modular Skid Unit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-3<br />
Cabin Module. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-4<br />
Winch Module . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-5<br />
Power Pack. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-6<br />
Mnemonics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .9-1<br />
<strong>Wireline</strong> <strong>and</strong> <strong>Perforating</strong> <strong>Services</strong> Mnemonics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .9-2<br />
Log Header Mnemonics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .9-44<br />
Table of Contents ix
x Table of Contents
Knowledge <strong>and</strong> Data Transfer<br />
Real-Time Operations<br />
Real-Time Data/Solution Delivery<br />
Various methods are used to deliver data in real time from<br />
wellsites to offsite locations. The three main methods are:<br />
• InSite Anywhere® service<br />
Collaborative formation evaluation <strong>and</strong> reservoir<br />
monitoring<br />
Real-time monitor <strong>and</strong> control (RTMC)<br />
InSite Anywhere® service moves data from the logging tools<br />
onto a secured website, where it can be viewed in real time as<br />
it is acquired. InSite Anywhere service is also a drop box for<br />
data files <strong>and</strong> viewing DHV images in real time.<br />
With collaborative formation evaluation <strong>and</strong> reservoir<br />
monitoring, it is possible to deliver data to environments<br />
where experts can discuss any issues dealing with geology,<br />
operations, or the reservoir, thereby influencing the ongoing<br />
services at the wellsite immediately.<br />
Real-time monitor <strong>and</strong> control (RTMC) is an internal tool<br />
that provides both operational <strong>and</strong> technical support along<br />
with ability to control remote wellsite locations.<br />
Features<br />
Scalable, from simple operations to the most<br />
sophisticated<br />
<strong>Halliburton</strong> expertise available<br />
Provides instant access <strong>and</strong> support from non-wellsite<br />
locations<br />
Personnel can participate in multiple operations<br />
Exp<strong>and</strong> personnel capabilities<br />
Knowledge <strong>and</strong> Data Transfer 1-1<br />
Knowledge <strong>and</strong> Data Transfer
HalLink ® Satellite Systems<br />
Three systems are available: l<strong>and</strong> (tripod), skid<br />
(compensating), <strong>and</strong> vessel (permanent). HalLink® systems<br />
allow transmission of data <strong>and</strong> video at high speeds through<br />
a secure network supporting all <strong>Halliburton</strong> real-time<br />
operations. With “last mile” connectivity to the location,<br />
real-time support <strong>and</strong> decisions can be made more easily.<br />
Features<br />
Fully scalable to client needs, simple point-to-point<br />
network through full mesh (point-to-many)<br />
Deployment can be exp<strong>and</strong>ed per client needs<br />
System is flexible, which enables the system to be part of<br />
the <strong>Halliburton</strong> or client network<br />
Two phone lines for operational support<br />
Improved reliability for wellsite connectivity<br />
B<strong>and</strong>width scalable to local/client needs<br />
<strong>Services</strong> Enabled by HalLink Systems<br />
Immediate data transfer for:<br />
– QuikLook® reservoir fluid management services<br />
– Applied formation evaluation processing<br />
InSite Anywhere® service<br />
–Downhole video<br />
– MRILab® downhole measurement service<br />
– RDT reservoir description tool<br />
– St<strong>and</strong>ard logging suite<br />
Collaborative formation evaluation <strong>and</strong> reservoir<br />
monitoring<br />
Real-time monitor <strong>and</strong> control<br />
Video conferencing Connectivity Anywhere<br />
1-2 Knowledge <strong>and</strong> Data Transfer
InSite Anywhere ® Service<br />
InSite Anywhere® service is a next-generation, web-based<br />
data delivery system that gives you the flexibility of the<br />
industry’s most robust database structure—without the need<br />
to install special software. Using our advanced satellite<br />
communications technology or any other network, InSite<br />
Anywhere service moves data from the logging tools onto a<br />
secured web site, where you can view it in real time as it is<br />
acquired.<br />
When an unplanned event arises, the InSite Anywhere web<br />
delivery system provides needed facts to comm<strong>and</strong> the<br />
situation. Whatever solution directed will be based on<br />
complete up-to-the-minute information. The system allows<br />
you to participate in multiple wellsite operations from one<br />
location. With all the travel time saved, capabilities are<br />
stretched further—<strong>and</strong> make the most of company resources.<br />
Features<br />
View <strong>and</strong> print logging <strong>and</strong> tester data in real time from<br />
any PC<br />
Access offset well data from nearby wells<br />
Download logging data, answer products, <strong>and</strong> more<br />
Configure display to individual preference by<br />
manipulating logging or test data<br />
View <strong>and</strong> print numerous display types:<br />
–Log plots<br />
– Pressure tests <strong>and</strong> samples<br />
– Streaming downhole video (view only or save/<br />
print to screen capture)<br />
– Cross-plots<br />
– MRILab® service results (view only or save/print<br />
as screen capture)<br />
– Efficient gauges, LEDs, <strong>and</strong> other indicators<br />
Exp<strong>and</strong> personnel capabilities<br />
Speed decision-making<br />
Participate in multiple operations<br />
Optimize logging passes<br />
Deploy expertise <strong>and</strong> resources more efficiently<br />
Save travel expenses<br />
Avoid travel risk<br />
No special hardware or software required<br />
Requirements for Service<br />
Internet or intranet access<br />
Uses st<strong>and</strong>ard web browsers<br />
User name, password, <strong>and</strong> URL<br />
Uses the security protections of the HalLink®<br />
commuciations network or any other secure network<br />
Knowledge <strong>and</strong> Data Transfer 1-3
1-4 Knowledge <strong>and</strong> Data Transfer
Reservoir Evaluation <strong>Services</strong><br />
Petrophysics<br />
MRI Petrophysics<br />
MRIL ® Simultaneous T 1 <strong>and</strong> T 2 Measurements<br />
Both the MRIL-XL <strong>and</strong> MRIL®-Prime tools acquire NMR<br />
data in several modes of operation. Simultaneous T 1 <strong>and</strong> T 2<br />
log acquisition is a robust technique to acquire NMR<br />
reservoir information faster <strong>and</strong> simpler. T 1 has made its<br />
wireline debut to join MRIL-WD (MRI while drilling) <strong>and</strong><br />
MRILab® service (MRI fluid analysis during wireline<br />
formation sampling). In both the MRIL-WD <strong>and</strong> MRILab<br />
applications, the preference of T 1 over T 2 has been its<br />
insensitivity to motion as T 1 measurements eliminate the<br />
detrimental effects from tool motion or fluid flow.<br />
Simultaneous T 1 <strong>and</strong> T 2 wireline acquisition is now done in a<br />
single log pass. Micro-porosity, capillary bound water, free<br />
fluid index, effective porosity, <strong>and</strong> total NMR porosity<br />
acquired during T 1 logging may be used in MRIAN<br />
analysis as described on page 2-2.<br />
T 1 logging offers a simplified NMR measurement composed<br />
of only two of the three decay mechanisms associated with<br />
NMR. Only surface <strong>and</strong> bulk relaxation mechanisms<br />
contribute to the T 1 response. There is no diffusion effect in<br />
T 1 data, so many fluid identification applications are<br />
simplified as in tight gas identification in water-based mud<br />
systems. For simple <strong>and</strong> faster NMR reservoir information,<br />
T 1 offers a reliable alternative to T 2 .<br />
Features<br />
Robust reservoir quality measurements of NMR<br />
Total <strong>and</strong> effective porosity <strong>and</strong> bound fluid volumes<br />
Light hydrocarbon identification<br />
Faster logging speeds<br />
Simplified NMR interpretation (no diffusion effects)<br />
Simultaneous T1 <strong>and</strong> T2 acquisition (single log pass)<br />
Real-time permeability calculations<br />
This T 1 MRIAN analysis example depicts the long T 1 gas signal in the<br />
upper zone, green waveforms on far right in Track 4. The free water T 1<br />
values are much shorter as can be seen in Track 4 in the lower zone.<br />
Reservoir Evaluation <strong>Services</strong> 2-1<br />
Reservoir Evaluation <strong>Services</strong>
MRIAN Magnetic Resonance Imaging Analysis<br />
MRIAN analysis is a technique that combines MRIL® <strong>and</strong><br />
conventional data to identify potential hydrocarbon zones.<br />
MRIAN analysis uses the dual-water model technique to<br />
estimate the volume of formation fluids in a virgin zone.<br />
Using the dual-water model within the MRIAN program<br />
allows identification of free water volume. When the<br />
computed effective volume of water equals the MRIL data<br />
irreducible volume of water, then production is water free.<br />
Both T 1 <strong>and</strong> T 2 distributions <strong>and</strong> permeability calculations<br />
are provided to indicate reservoir quality.<br />
MRIL st<strong>and</strong>-alone analyses, such as time domain analysis<br />
(TDA), diffusion analysis (DIFAN), <strong>and</strong> Enhanced Diffusion<br />
Method (EDM) technique provide hydrocarbon typing<br />
interpretation within the depth of investigation of the MRIL<br />
measurements. When MRIL data is combined with other<br />
logs, analysis can furnish even more information about the<br />
reservoir. MRIAN analysis is one of the interpretation<br />
models that use this data combination.<br />
Features<br />
MRIAN analysis combines MRIL analysis <strong>and</strong> deepresistivity<br />
data from any induction tool. MRIL data is used to<br />
provide two important parameters needed in the dual-water<br />
model: the clay-bound water porosity (MCBW) <strong>and</strong> total<br />
porosity (MPHIT).<br />
Additional features include the following:<br />
Provides enhanced permeability calculations<br />
Indicates zones of potential water production<br />
Identifies hydrocarbon-water contacts<br />
Calculates water saturation in the uninvaded zone<br />
Provides a solution for low-resistivity pay reservoirs<br />
Confirms dual-water Rw by reconstructing spontaneous<br />
potential (SP)<br />
Uses a robust implementation of the dual-water<br />
resistivity model to provide improved water saturation<br />
(Sw) calculations, especially in shaly reservoirs<br />
This MRIAN analysis indicates an oil/water contact at X940. The MRI<br />
T 2 distribution in Track 3 demonstrates a change in relaxation times<br />
verifying the MRIAN analysis.<br />
2-2 Reservoir Evaluation <strong>Services</strong><br />
HAL9111
Inputs<br />
HAL9112<br />
This MRIAN analysis example demonstrates the effectiveness of<br />
this model to identify oil/water contact as well as zones of potential<br />
water production (Track 4). Enhanced permeability calculations are<br />
presented in Track 2 (red curve).<br />
MRIL ® porosity data. The main data requirements for MRIAN processing are true formation resistivity (R t), total porosity<br />
(φ t ), <strong>and</strong> clay-bound-water saturation (S wb ). Density, neutron, <strong>and</strong>/or sonic porosity are optional inputs. MRIL activation<br />
planning is critical for successful interpretation.<br />
Outputs Permeability, effective porosity, total porosity, water saturation, free water volume, irreducible water volume<br />
Reservoir Evaluation <strong>Services</strong> 2-3
Time Domain Analysis (TDA)<br />
MRIL® data can be analyzed independently or in<br />
combination with conventional logs. When MRIL data is<br />
processed independently, it can provide formation porosity<br />
<strong>and</strong> permeability information as well as complete<br />
information on fluid types <strong>and</strong> fluid saturation within the<br />
depth of investigation of the MRIL tool. Time domain<br />
analysis (TDA) is an interpretation technique that utilizes<br />
only MRIL data.<br />
Time domain analysis operates on the principle that different<br />
fluids have different rates of polarization or different T 1<br />
relaxation times. The T 1 of both gas <strong>and</strong> light oil (viscosity<br />
less than 5 cp) is normally much higher than that of water.<br />
TDA is very effective in evaluating gas <strong>and</strong> light oil reservoirs.<br />
TDA is very different from other techniques available<br />
because it uses only MRIL data in the interpretation process;<br />
no conventional data is needed in the processing.<br />
Features<br />
TDA analysis provides an alternative to the differential<br />
spectrum method for processing dual-Tw echo trains data.<br />
Interpretation is performed in the time domain rather than<br />
in the T2 spectra domain. Key features of TDA analysis<br />
include:<br />
Subtraction of the two echo trains from one another<br />
Processing echo differences in the time domain using<br />
predicted or measured oil, gas, <strong>and</strong> water relaxation<br />
times <strong>and</strong> hydrogen-index values<br />
Additional TDA features include the following:<br />
Provides accurate formation porosity in gas <strong>and</strong> light oil<br />
reservoirs<br />
Allows complete fluid volume analysis within the depth<br />
of investigation of the MRIL tool using only MRIL tool<br />
data<br />
Provides hydrocarbon typing<br />
Recognizes direct pay<br />
Improves permeability calculations in light hydrocarbon<br />
environment<br />
Clearly identifies pay zones vs. tight zones<br />
Inputs<br />
Estimates free fluid volume <strong>and</strong> type in thinly laminated<br />
reservoirs<br />
Indicates the best possible producing zones in carbonate<br />
formation<br />
This MRIAN analysis example demonstrates the effectiveness of this<br />
model to identify oil/water contact as well as zones of potential water<br />
production (Track 4). Enhanced permeability calculations are<br />
presented in Track 2 (red curve).<br />
MRIL ® data only from dual-wait time acquisition which can be acquired using MRIL-XL, MRIL ® -Prime <strong>and</strong>/or<br />
MRIL-WD tools<br />
Outputs Volumetric calculation of gas, oil, <strong>and</strong> water; formation total <strong>and</strong> effective porosity; permeability estimation<br />
2-4 Reservoir Evaluation <strong>Services</strong><br />
HAL9113
Diffusion Analysis (DIFAN)<br />
Diffusion analysis (DIFAN) is a st<strong>and</strong>-alone NMR technique<br />
for quantitative diffusion analysis of intermediate oil<br />
viscosity range of 2 to 30 cp <strong>and</strong> has been applied successfully<br />
in many fields. DIFAN was developed specifically for<br />
situations where TDA cannot be applied because of<br />
insufficient T 1 contrast. Variations in molecular diffusion<br />
will manifest themselves as variations in the observed T 2<br />
distributions. These can be used to quantify water-filled <strong>and</strong><br />
oil-filled porosity, respectively.<br />
Features<br />
Diffusion analysis is an interpretation technique utilizing<br />
dual-T E measurements. DIFAN relies on the diffusion<br />
contrast between water <strong>and</strong> medium viscosity oil to quantify<br />
oil volume within the depth of investigation of the tool. The<br />
data for DIFAN is acquired through single-T W (wait time),<br />
dual-T E (echo spacing) logging.<br />
Other features of diffusion analysis include:<br />
Calculates hydrocarbon <strong>and</strong> water saturation in<br />
freshwater environments<br />
St<strong>and</strong>-alone analysis does not need resistivity logs<br />
Works in low to moderate viscosity oils (typically 2 to<br />
30 cp at reservoir conditions)<br />
Works in areas of unknown or variable Rw Inputs MRIL ® data (dual-T E activation) from MRIL-XL or MRIL ® -Prime tools<br />
Outputs Porosity, S w , diffusion ratios, permeability, watercut (if relative permeabilities are known)<br />
This log contains results from the application DIFAN to MRIL® data<br />
from an Indonesian well. Track 1 includes conventional gamma ray,<br />
spontaneous potential, <strong>and</strong> caliper curves. Track 2 presents deep,<br />
medium, <strong>and</strong> shallow resistivity data <strong>and</strong> MRIL permeability. Track 3<br />
contains the long-T E T 2 distribution. Track 4 contains the short-T E T 2<br />
distribution. Track 5 displays answer products from DIFAN<br />
calculations.<br />
Reservoir Evaluation <strong>Services</strong> 2-5<br />
HAL9114
Enhanced Diffusion Method (EDM) Technique<br />
Enhanced Diffusion Method (EDM) NMR technique<br />
utilizes the contrast in molecular diffusion between water<br />
<strong>and</strong> oil to identify <strong>and</strong> potentially quantify oil<br />
accumulations. The diffusion properties of water, combined<br />
with tool parameters (T E, magnetic field gradient) <strong>and</strong> the<br />
temperature of the logging environment, define the slowest<br />
relaxation time possible for water to be observed: T 2DW.<br />
Consequently, any NMR signal observed beyond this value<br />
can only be associated with oil. This offers a simple way to<br />
interpret the presence of oil <strong>and</strong> to differentiate pay from<br />
non-pay zones.<br />
The EDM technique can also be used to quantify residual oil.<br />
The advantage it has over conventional techniques such as<br />
pressure-coring <strong>and</strong>/or sponge-coring is that oil is measured<br />
at in-situ conditions. Hence, gas expansion or fluid expulsion<br />
need not be taken into account. As with any residual oil<br />
determination technique, controlling fluid loss from the mud<br />
system to the formation is critical to the overall success of the<br />
EDM technique.<br />
Features<br />
EDM interpretation methodology is based on the contrasts<br />
in molecular diffusion between different fluids.<br />
Enhancement of the diffusion effect, by increasing the interecho<br />
spacing T E during data acquisition, separates water <strong>and</strong><br />
oil in the T 2 domain.<br />
HAL9115<br />
For typing medium-viscosity oils with this method, st<strong>and</strong>ard<br />
CPMG T 2 data recorded with a long T E is sufficient.<br />
Quantitative application of the EDM technique requires<br />
either dual-T W data recorded with a long T E , or dual-T E data<br />
recorded with a long T W.<br />
Additional features include:<br />
Independent confirmation of oil-bearing zones <strong>and</strong><br />
identification of oil/water contacts<br />
St<strong>and</strong>-alone determination of (residual) oil saturation<br />
with no need to dope drilling fluids<br />
Sensitive to oil in the viscosity range from 1 cp to 50 cp<br />
Works in areas of unknown or variable Rw Enhanced Diffusion Method technique can differentiate pay from non-pay zones. Track 5 indicates an oil/water contact near the bottom <strong>and</strong> the<br />
oil column continues to the top of the zone. This finding is supported by the resistivity curves in Track 2.<br />
Inputs MRIL ® data (dual-T E activation) from MRIL-XL, MRIL ® -Prime, or MRIL-WD tools<br />
Outputs Residual oil saturation, porosity, permeability, viscosity, flushed zone S w<br />
2-6 Reservoir Evaluation <strong>Services</strong>
Heavy Oil MRIANSM Service<br />
The heavy oil MRIANSM service improves reservoir<br />
evaluation in areas where oil viscosity exceeds 100 cp at<br />
formation conditions, <strong>and</strong> the oil gravity is less than 20° API.<br />
The heavy oil MRIAN service combines dual-echo spacing<br />
MRIL® logs with conventional porosity <strong>and</strong> resistivity logs to<br />
provide improved:<br />
Determination of bulk volume irreducible (BVI)<br />
Measurement of movable water<br />
Quantification of viscous oil reserves<br />
Estimation of permeability in water-wet reservoirs<br />
By themselves, NMR responses to viscous oils are not readily<br />
distinguishable from those of capillary-bound <strong>and</strong> claybound<br />
water. The heavy oil model is able to differentiate<br />
these fluids by using MRIL® data to quantify movable water<br />
in the formation. This volume, when subtracted from the<br />
effective water volume derived from conventional logs, gives<br />
the irreducible water volume. In addition, this comparison is<br />
useful for recognizing mixed or oil-wet reservoir conditions,<br />
which can often occur in viscous-oil reservoirs.<br />
Good c<strong>and</strong>idates for application of the heavy oil MRIAN<br />
service are heavy oil producing areas in Venezuela, Canada,<br />
Alaska, Russia, <strong>and</strong> smaller heavy oil provinces throughout<br />
the world. This service has been successfully applied in both<br />
s<strong>and</strong>stone <strong>and</strong> carbonate reservoirs.<br />
Features<br />
An integrated NMR <strong>and</strong> conventional log heavy oil<br />
interpretation model<br />
Movable water determination in heavy oil-bearing<br />
formations using the Enhanced Diffusion Method<br />
(EDM)<br />
Comparison of NMR <strong>and</strong> conventional porosity<br />
responses to estimate in-situ oil viscosity<br />
Improved BVI determination compared to traditional<br />
interpretation of NMR measurements in heavy-oil<br />
reservoirs<br />
Can provide a complete analysis of pore fluids, including<br />
clay-bound <strong>and</strong> capillary-bound pore fluids, movable<br />
water volume, <strong>and</strong> hydrocarbon volumes<br />
Direct measurement of movable water<br />
Inputs MRIL ® data acquired with dual-T E <strong>and</strong> conventional data<br />
Aid improved water saturation evaluation<br />
Indication of moved hydrocarbons in the near-wellbore<br />
region<br />
Determination of in-situ oil viscosity from MRIL signalloss<br />
in heavy oil-bearing formations<br />
Indication of formation wettability conditions<br />
The log above shows results from a heavy oil MRIAN analysis of data<br />
collected from an area of the United Kingdom continental shelf. These<br />
results show the reservoir is mostly water-wet through the transition<br />
zone. The absence of capillary bound water above the transition zone<br />
indicates an oil-wet condition.<br />
Outputs Corrected BVI, clay porosity, total porosity, improved permeability estimates, effective porosity, water saturations, viscosity<br />
Reservoir Evaluation <strong>Services</strong> 2-7<br />
HAL9116
StiMRIL Process<br />
The StiMRIL process is an integrated stimulation process<br />
built upon a reservoir performance model created from a<br />
combination of MRIL® magnetic resonance imaging logging<br />
analyses <strong>and</strong> reservoir simulations. This model allows the<br />
stimulation design engineer to develop optimum<br />
completion/stimulation plans <strong>and</strong> accurately predict the<br />
outcome of production enhancement efforts. Identification<br />
of hydrocarbon type <strong>and</strong> accurate determinations of<br />
porosity, free fluid, <strong>and</strong> bound fluid volumes from MRIL<br />
logging measurements provide operators with answers to<br />
critical questions by providing:<br />
The location of oil, gas, or water in the zone<br />
The potential for water production<br />
The net present value (NPV) of the zone<br />
The rate at which the well will produce oil, gas, or water can<br />
then be predicted by carrying this information forward in the<br />
reservoir simulation step of the StiMRIL process.<br />
The MRIL® tool is used to perform high-quality<br />
measurements <strong>and</strong> collect the data required to make a<br />
thorough reservoir evaluation in a single logging pass. In<br />
addition to saving rig time, the resulting calculations of<br />
permeability, water saturation, <strong>and</strong> effective porosity are<br />
better than those derived from other lithology-dependent<br />
methods.<br />
Features<br />
The reservoir modeling capabilities included in the StiMRIL<br />
process use the results of the MRIL analysis to provide a<br />
relatively complete representation of the reservoir's<br />
production characteristics. An integrated stimulation design<br />
process allows operators to accurately predict reservoir<br />
performance <strong>and</strong> to optimize their financial investment<br />
based on the economics of the fracturing treatment for the<br />
reservoir. For example, in a tight-gas s<strong>and</strong> (low permeability<br />
formation), the completion design usually centers around a<br />
hydraulic treatment.<br />
Other features include:<br />
Increased focus on the reservoir through the integration<br />
of well logging, reservoir performance, <strong>and</strong> stimulation<br />
design<br />
Logging data <strong>and</strong> reservoir simulations used in<br />
combination to increase reservoir underst<strong>and</strong>ing<br />
Built-in stimulation design capabilities to help operators<br />
develop the best completion strategies<br />
Here is an example of a layered s<strong>and</strong>stone reservoir which indicates a<br />
high clay, low porosity interval in the lower section of the well, cleaner<br />
zones with higher movable hydrocarbons in the middle, <strong>and</strong> an<br />
extremely high perm zone in the top, which contains a large amount<br />
of oil.<br />
2-8 Reservoir Evaluation <strong>Services</strong><br />
HAL9117
MRIL® logging has revolutionized the logging industry<br />
through its ability to directly <strong>and</strong> accurately measure the<br />
fluids in the reservoir. This results in the accurate<br />
determination of:<br />
Porosity <strong>and</strong> permeability<br />
Fluid type <strong>and</strong> viscosity changes<br />
Irreducible water volume <strong>and</strong> free fluid volume<br />
In other words, MRIL logs indicate not only whether there is<br />
oil or gas in a zone but also where it is located within the<br />
zone. These logs also show how much water is present in the<br />
zone, how it is distributed throughout the zone, <strong>and</strong> whether<br />
it is free to move to the wellbore <strong>and</strong> interfere with<br />
hydrocarbon production. Before the StiMRIL process was<br />
developed, fracturing designs relied on lithological volumes<br />
from quad-combo logging data to provide the information<br />
to qualitatively evaluate zones <strong>and</strong> calculate fracture<br />
geometry. With the StiMRIL process, engineers are able to<br />
incorporate MRIL logging data into the design to predict<br />
productivity results. Quad-combo logs still provide the<br />
lithology information, while MRIL logs provide the fluid<br />
dynamics information.<br />
The result is optimized treatment designs for maximum,<br />
predictable well productivity <strong>and</strong> improved profitability for<br />
the operator.<br />
Inputs Pore-size distribution, permeability, effective porosity, total porosity, water saturation, gas indicator<br />
Outputs Initial production rate, time of recovery, porosity, permeability, Young's modulus, Poisson's ratio optimum NPV for the well<br />
Reservoir Evaluation <strong>Services</strong> 2-9
Volumetric Petrophysics<br />
Chi Modeling ® Computation Service<br />
Some open-hole wells have difficult logging conditions that<br />
may result in missed zones of open-hole information, or in<br />
extreme conditions, even the loss of the entire open-hole<br />
logging run. <strong>Halliburton</strong> now provides Chi Modeling®<br />
computation post-processing service will help the user to<br />
better evaluate their reservoir when they have missing data<br />
due to borehole conditions, missing LWD sections, old wells,<br />
etc. Chi Modeling computation service is able to predict<br />
triple-combo or even quad-combo open-hole data with a<br />
very high degree of accuracy by using the input data obtained<br />
from a capture pass of a pulsed neutron tool <strong>and</strong> a known<br />
triple-combo or quad-combo data set from a neighboring<br />
well. Under some conditions, missing or incorrect data<br />
caused by tool pulls or intermittent sensor failure can be<br />
correctly generated using only the triple-combo data. Chi<br />
Modeling computation is also able to:<br />
Fill in data gaps where the original data is missing from<br />
either wireline or LWD data<br />
Replace poor quality data that occurred due to poor<br />
borehole conditions<br />
Generate reliable open-hole logs when none are available<br />
Chi Modeling computation service uses associations made in<br />
one well between an existing open-hole triple-combo <strong>and</strong> a<br />
cased-hole pulsed neutron tool. It does this by looking at<br />
data from a reference well <strong>and</strong> assigning a processing weight<br />
to each input variable.<br />
If the predicted values do not match the actual value in the<br />
reference well adequately, the weights are changed, <strong>and</strong> the<br />
model is re-computed. These associations are then used,<br />
along with pulsed neutron data from an offset well, to model<br />
a triple-combo or quad-combo response in an offset well.<br />
These associations may be confidently used as long as:<br />
The formation geology remains similar<br />
The formations geology is adequately sampled <strong>and</strong><br />
represented in the reference well<br />
When the formation geology from the reference well<br />
changes, a new set of open-hole data is required to create a<br />
new set of associations. This method retains the variability of<br />
the original data <strong>and</strong> does not over predict mean statistical<br />
values.<br />
A root mean square (RMS) statistical analysis is performed<br />
on each curve generated in the base well to confirm the<br />
reliability of the data associations that will be used to project<br />
<strong>and</strong> predict the offset triple-combo or quad-combo data.<br />
Normal accuracy results are as follows:<br />
Density ± .034 gm/cc = ±2PU<br />
Neutron ±2PU<br />
Resistivity ± .1 decade<br />
50%<br />
25%<br />
25%<br />
Train<br />
Validate<br />
Test<br />
Figure 1 indicates that Chi Modeling software uses training data<br />
from the reference well in conjunction with weights for each input<br />
variable to generate predictions. The weights are then applied to the<br />
entire reference well to generate predictions. The values obtained are<br />
validated <strong>and</strong> tested against the original open-hole data. If they do<br />
not match, new weights are used until a match is obtained.<br />
2-10 Reservoir Evaluation <strong>Services</strong><br />
HAL12892
HAL12893<br />
Figure 2 shows the normal input data going into the Chi Modeling software. The weights used for data prediction are<br />
refined until a reasonable match is obtained with the open-hole data from the reference well. These relationships are used to<br />
predict <strong>and</strong> construct triple-combo data on offset wells that have only pulsed neutron data available.<br />
HAL12894<br />
Figure 3 shows a comparison between the original neutron/density porosity data (Track 3) <strong>and</strong> the predicted neutron/<br />
density porosity data for a reference well (Track 4) as well as the original (black) <strong>and</strong> predicted (red) 90-in. resistivity<br />
data (Track 2). Track 1 is the open-hole gamma ray.<br />
Reservoir Evaluation <strong>Services</strong> 2-11<br />
Chi<br />
®
ULTRA Module Suite<br />
ULTRA products are a suite of interactive <strong>and</strong> noninteractive<br />
modules which process well log data to make<br />
comprehensive formation evaluation computations<br />
determining mineral volumes <strong>and</strong> fluid saturations. The<br />
ULTRA tool uses a weighted least-squares error optimization<br />
technique to determine fractional lithology constituents<br />
(clay, s<strong>and</strong>stone, limestone, <strong>and</strong> other minerals) <strong>and</strong> the<br />
percent of saturation of individual fluid components which<br />
occupy total pore space.<br />
PREPARE is a query-based module that leads the user<br />
through the basic parameter entries necessary for later use in<br />
other modules of ULTRA data. It is obligatory to use either<br />
PREPARE or JOBVAR before proceeding with the processing<br />
of modules in the ULTRA suite.<br />
LOGQUAL calculates the uncertainty or quality of each log<br />
using all levels. These log uncertainties are used as weighting<br />
factors in the minimization process in CORINV, ULFE, <strong>and</strong><br />
AUTOMOD. The log curve names in the CLS file must be<br />
properly mapped into generic curve names used in the<br />
ULTRA suite via the group NAMLOG under JOBVAR.<br />
LOGQUAL must be run prior to any quantitative evaluation<br />
done under the routines CORINV, ULFE, <strong>and</strong> AUTOMOD.<br />
DATRED is used to square or block the logs. It provides nine<br />
different levels of squaring, ranging from coarse to fine, any<br />
of which may be selected during interactive processing to<br />
reduce the processing time. This routine must be run before<br />
CORINV, ULFE, or AUTOMOD.<br />
CORINV is designed to compute R t, R xo, <strong>and</strong> D i using any<br />
combination of resistivity logs. It has distinct advantages<br />
over the chart book approach when more than three<br />
resistivity logs are available <strong>and</strong> one or more logs in the suite<br />
have different degrees of reliability. The technique is based on<br />
a constrained weighted least squares error optimization<br />
using the inverse approach, wherein maximum likelihood<br />
values of R t, R xo, <strong>and</strong> D i are computed. Graphical<br />
comparisons of theoretical <strong>and</strong> measured log curves are used<br />
to determine the reliability of measurements.<br />
An interactive part of CORINV allows the log analyst to test<br />
hypotheses <strong>and</strong> to try various options to use weight<br />
multipliers <strong>and</strong> constraints. When the analyst is satisfied with<br />
the results, noninteractive option is used during which all<br />
data points in the zone selected are processed <strong>and</strong> computed<br />
results are written into the CLS file.<br />
HAL986<br />
This ULTRA log presents a light hydrocarbon indicator <strong>and</strong> water<br />
saturation in Track 1; volumes of residual hydrocarbons, movable<br />
hydrocarbons, <strong>and</strong> water in Track 2; <strong>and</strong> lithology analysis in Track 3.<br />
ULFE is used to perform log analysis involving the evaluation<br />
of constituent volume fractions of the rock <strong>and</strong> estimation of<br />
fluid saturations in the pore. A weighted least squares error<br />
optimization technique, using the inverse approach is<br />
employed. The analyst inputs the lithology, selects the<br />
response equations, enters the clay <strong>and</strong> mineral parameters,<br />
<strong>and</strong> geological constraints, etc. via the alpha-numeric edit<br />
screen. The data is then processed to obtain the statistically<br />
most probable results.<br />
The output is presented as graphical display of computed<br />
results, including formation bulk volume analysis <strong>and</strong> pore<br />
volume analysis, <strong>and</strong> a display of measured logs overlain by<br />
the theoretical or reconstructed logs. Theoretical logs are<br />
obtained by back computing the log values from the<br />
computed results. The degree of fit between the two sets of<br />
logs is a measure of the validity of the assumptions implicit<br />
in the model used.<br />
2-12 Reservoir Evaluation <strong>Services</strong>
Output can also be presented as a statistical display on an<br />
alphanumeric screen. The arithmetic average <strong>and</strong> the<br />
variance of the difference between each of the measured <strong>and</strong><br />
theoretical logs over the zone processed is individually<br />
displayed. Also the total error, which represents the<br />
summation of the errors for each of the constituent logs over<br />
the zone, is displayed. If the fit between the measured <strong>and</strong> the<br />
theoretical logs is poor, the analyst can modify the lithology,<br />
vary the clay <strong>and</strong> mineral parameters <strong>and</strong> try out the<br />
different response equations until a satisfactory fit is<br />
obtained, <strong>and</strong> results correspond to geological expectations.<br />
Results are computed <strong>and</strong> displayed on the screen but are not<br />
written to the disk in the interactive ULFE. Non-interactive<br />
processing is the next step where all data points are<br />
processed, <strong>and</strong> all computed results are written to the disk.<br />
The AUTOMOD primary objective is to provide optimized<br />
values for parameters or constants. In addition to the<br />
weighted least squares error optimization in ULFE for<br />
computing the variables like S w , V cl , Phi etc., the AUTOMOD<br />
routine also performs a zone wide optimization on a set of<br />
constants or parameters to provide optimized values for the<br />
constants. The constants that can be optimized include all<br />
parameters associated with s<strong>and</strong>, lime, dolomite, minerals 1<br />
through 9, clay, formation water resistivity, hydrocarbon<br />
density, cementation factor, <strong>and</strong> saturation exponent. The<br />
parameters to be optimized are set to the variable status. The<br />
log analyst furnishes an initial value <strong>and</strong> minimum <strong>and</strong><br />
maximum values within which parameters are to be<br />
optimized. Computations are then made over the entire<br />
interval selected for analysis using various values of the<br />
parameters to be optimized. The incoherence between the<br />
measured logs <strong>and</strong> the logs reconstructed from computed<br />
variables is then analyzed. The parameters' values that yield<br />
Inputs<br />
the least incoherence between the measured <strong>and</strong><br />
reconstructed logs over the interval selected for analysis are<br />
considered to be the optimized values of the parameters.<br />
AUTOMOD is the automatic modeling to optimize<br />
unknown parameters—an especially useful feature in<br />
exploration wells where data is scarce.<br />
Features<br />
Provides the analyst with statistically optimum<br />
computations of:<br />
–Porosity<br />
–Water saturation<br />
–Multi-mineral volumes<br />
–Hydrocarbon density<br />
Uses all available log data simultaneously<br />
– Provides powerful quality control features<br />
– Cross-checks final interpretation results<br />
– Validates tool calibration <strong>and</strong> performance<br />
– Validates interpretive model <strong>and</strong> zone constants<br />
Interactive testing <strong>and</strong> refinement of interpretation<br />
parameters <strong>and</strong> models<br />
Allows combination of core analysis information with<br />
log measurements to help ensure accurate results<br />
Allows the analyst to use zoned constants <strong>and</strong><br />
interpretive model selection in multiple wells to facilitate<br />
field study applications<br />
Minimum: at least one porosity measurement, resistivity, <strong>and</strong> GR or SP for shale volume ideal: all minimum inputs, plus<br />
caliper, Rxo-resistivity device, additional porosity sensors, MRIL ® , Spectral GR, <strong>and</strong> Sonic<br />
Outputs S w, S xo, V sh, φ eff, lithology, hydrocarbon weight, permeability, plus volumetric percent of selected minerals<br />
Reservoir Evaluation <strong>Services</strong> 2-13
SASHA Shaly S<strong>and</strong> Analysis<br />
SASHA analysis provides volumetric evaluation of gas, oil,<br />
<strong>and</strong> water in shaly s<strong>and</strong>s <strong>and</strong> uses traditional density/neutron<br />
crossplot as the basis of its volumetric analysis. A variety of<br />
water saturation <strong>and</strong> permeability models are available to<br />
optimize the petrophysical analysis to the reservoir.<br />
The oil <strong>and</strong> gas company can use conventional wireline or<br />
LWD log data to evaluate potential hydrocarbon production<br />
from predominately shaly/s<strong>and</strong> depositional environments<br />
by using the results of this analysis. SASHA analysis produces<br />
a summary of the lithology in terms of percent volume shale,<br />
s<strong>and</strong>stone silt, dispersed clay, coal, <strong>and</strong> salt. It includes logic<br />
for detection <strong>and</strong> correction for salt, rugosity, <strong>and</strong> gas. It also<br />
computes water saturation (S w), lithology, effective porosity<br />
(φ eff), hydrocarbon density, <strong>and</strong> relative permeabilities in<br />
shaly/s<strong>and</strong> reservoirs.<br />
A number of different water saturation models may be<br />
chosen. Input from the client as to previous analysis or<br />
model preferences could avoid unnecessary guessing.<br />
SASHA analysis can also produce a summary table of net pay,<br />
porosity feet, <strong>and</strong> hydrocarbon feet for each potential zone of<br />
interest.<br />
Environmental corrections for the resistivity <strong>and</strong> porosity<br />
devices should be done prior to running SASHA analysis.<br />
Applications<br />
Formation lithology analysis<br />
Porosity, saturation, <strong>and</strong> hydrocarbon flags<br />
Overview of potential pay zones over the well<br />
Inputs<br />
Features<br />
Robust, traditional cross-plot approach<br />
Multiple saturation <strong>and</strong> permeability models<br />
Calculation of hydrocarbon density<br />
Summary table of each pay interval<br />
Minimum: at least one porosity measurement, resistivity, <strong>and</strong> GR or SP for shale volume<br />
Ideal: All minimum inputs, plus caliper, additional porosity, Spectral GR, <strong>and</strong> Sonic<br />
Outputs S w, S xo, V sh, φ eff, lithology, hydrocarbon weight, permeability<br />
Example SASHA analysis showing (l-r) shale/s<strong>and</strong> volumetric analysis;<br />
hydrocarbon weight analysis with oil (red) <strong>and</strong> gas (pink) volumes <strong>and</strong><br />
pay flag (black); saturation analysis; relative permeability analysis<br />
2-14 Reservoir Evaluation <strong>Services</strong><br />
HAL9120
CORAL Complex Lithology Analysis<br />
CORAL complex lithology analysis helps evaluate the<br />
potential production from complex or mixed lithology<br />
reservoirs using wireline or LWD log data.<br />
CORAL analysis computes water saturation (S w), lithology,<br />
effective porosity (φ eff) <strong>and</strong> relative permeabilities in<br />
carbonates <strong>and</strong> complex lithology reservoirs.<br />
CORAL analysis produces an analysis of the lithology in<br />
terms of percent volume shale, limestone, dolomite,<br />
s<strong>and</strong>stone, coal, <strong>and</strong> salt. It includes logic for detection <strong>and</strong><br />
correction for salt, rugosity, <strong>and</strong> gas.<br />
CORAL analysis uses a traditional crossplot-based formation<br />
evaluation approach to determine shale volume, effective<br />
porosity, <strong>and</strong> water saturation. CORAL analysis also<br />
estimates relative permeabilities from several different<br />
models.<br />
A number of different water saturation models may be<br />
chosen. Input from the client as to previous analysis or<br />
model preferences could avoid unnecessary guessing.<br />
CORAL analysis also can produce a summary table of net<br />
pay, porosity feet, <strong>and</strong> hydrocarbon-feet for each potential<br />
zone of interest.<br />
Environmental corrections for the resistivity <strong>and</strong> porosity<br />
devices should be done prior to running CORAL analysis.<br />
Applications<br />
Formation lithology analysis<br />
Porosity, saturation, <strong>and</strong> gas flags<br />
Pay zone evaluation summary<br />
Overview of potential pay zones over the well<br />
Features<br />
Robust, traditional crossplot-based approach<br />
Flexibility for almost all lithology mixtures<br />
Multiple saturation <strong>and</strong> permeability models<br />
Summary table of each pay interval<br />
Inputs<br />
Minimum: Neutron, Density, Resistivity, <strong>and</strong> GR or SP.<br />
Ideal: All minimum inputs, plus Caliper, Spectral GR, Sonic, <strong>and</strong> Pe.<br />
Outputs S w , S xo , V sh , φ eff , Lithology volume percent, permeability<br />
Example of CORAL log analysis in late Pennsylvanian carbonates <strong>and</strong><br />
s<strong>and</strong>s.<br />
Reservoir Evaluation <strong>Services</strong> 2-15<br />
HAL9121
LARA Laminated Reservoir Analysis<br />
Many highly-laminated reservoirs have been missed in<br />
existing wells due to the coarse vertical resolution of older<br />
logging tools <strong>and</strong> the inadequate analysis techniques of<br />
traditional interpretation programs. To better detect <strong>and</strong><br />
study thin-bed reservoirs, it has been necessary to develop<br />
new logging tools, post-processing techniques, <strong>and</strong> data<br />
analysis methods.<br />
High-resolution shale indicators allow separation of the s<strong>and</strong><br />
<strong>and</strong> shale components but still require thin bed resolution of<br />
true formation resistivity <strong>and</strong> porosity. The measurements<br />
produced by high resolution shale indicators are used with<br />
those from conventional or resolution-enhanced porosity<br />
logging tools to improve the saturation analysis of the<br />
laminated reservoir. This is the basis of LARA laminated<br />
reservoir analysis.<br />
To determine shale volume, the high-resolution shale device<br />
data is first integrated to the vertical resolution of the<br />
porosity device. Then two medium-resolution shale volumes<br />
are calculated—one from the integrated high-resolution data<br />
<strong>and</strong> one from the porosity data. Device-specific shale<br />
parameters are automatically adjusted until the two volumes<br />
are equal. Then LARA analysis calculates the conventional<br />
total <strong>and</strong> effective porosities. It also determines the mode of<br />
clay distribution, i.e., dispersed or laminated.<br />
The high-resolution shale volumes are then used with the<br />
known shale resistivity to generate high resolution resistivity<br />
expressions that involve shale <strong>and</strong> non-shale volumes <strong>and</strong><br />
resistivities. These expressions are integrated to the vertical<br />
resolution of the resistivity device. The integrated resistivity<br />
is equated to the measured resistivity, <strong>and</strong> the resulting<br />
equation solved to give the non-shale resistivity, which is<br />
essentially a shale-corrected true formation resistivity (R t).<br />
Finally, the calculated effective porosity <strong>and</strong> true formation<br />
resistivity are used in a modified Waxman-Smits equation to<br />
calculate S w .<br />
Applications<br />
Resolving gross shale volume percent to high resolution<br />
laminated <strong>and</strong> dispersed clay content<br />
Detection of thin-bed reservoirs<br />
Improve saturation analysis of the laminated reservoir<br />
Inputs<br />
Features<br />
High-resolution shale indicator generally yields<br />
significantly more accurate analysis in laminated<br />
reservoirs than st<strong>and</strong>ard shaly s<strong>and</strong> models<br />
Helps with the reliable quantitative interpretation of<br />
thinly laminated reservoirs<br />
Helps identify potential hydrocarbon production often<br />
missed by conventional analysis<br />
Thinly laminated hydrocarbon bearing zones above the main clean s<strong>and</strong><br />
pay zones would have been overlooked with conventional log analysis.<br />
In this case, high resolution data from the EMI image tool was<br />
integrated into the LARA analysis. Note the gas effect density-neutron<br />
crossover in the clean s<strong>and</strong>s <strong>and</strong> lack of crossover in the thinly<br />
laminated zone above the clean s<strong>and</strong> zone.<br />
2-16 Reservoir Evaluation <strong>Services</strong><br />
HAL9123<br />
In addition to the minimum of a GR, resistivity <strong>and</strong> porosity measurement, one or more of the following thin-bed shale indicator inputs<br />
is required for LARA analysis: SED, Pe (unfiltered), Microresistivity (ML, MSFL), CAST, EMI, XRMI, OMRI, EVR-GR.<br />
The best high-resolution shale indicators are six-arm dipmeter or EMI, XRMI, OMRI, but alternatives include all of the above. LARA<br />
program requires only a single porosity device but yields better results when more than one is used.<br />
Outputs S w, S xo, V SH, φ eff, lithology hydrocarbon weight (oil, gas), permeability
Reservoir Characterization<br />
Borehole Image Analysis<br />
AutoDip <strong>and</strong> TrendSetter <strong>Services</strong><br />
AutoDip <strong>and</strong> TrendSetter services automate dip <strong>and</strong> dip<br />
trend analysis of EMI, XRMI, <strong>and</strong> OMRI borehole<br />
data. These services save time <strong>and</strong> provide high-quality data<br />
that can help spot “hidden features” in sedimentary beds <strong>and</strong><br />
laminates.<br />
AutoDip service automates high-resolution dip detection—a<br />
vast improvement on tedious manual dip picking. Unlike<br />
traditional dip computation methods, AutoDip service does<br />
not simply correlate raw resistivity data. This method<br />
operates independently of often inappropriate correlation<br />
parameters, such as correlation length, step length, <strong>and</strong><br />
search angle.<br />
TrendSetter service augments AutoDip functionality by<br />
taking dip data <strong>and</strong> automatically sorting it into categories:<br />
Constant dip with depth<br />
Increasing dip with depth<br />
Decreasing dip with depth<br />
TrendSetter service helps characterize geologic features based<br />
on dip trends. AutoDip <strong>and</strong> Trendsetter services provide a<br />
continuous plot with a break out of dip trends <strong>and</strong> constant<br />
dips. These dips <strong>and</strong> trends can be easily recognized <strong>and</strong><br />
incorporated into a geological model.<br />
AutoDip <strong>and</strong> TrendSetter services differentiate themselves by<br />
selecting bedding features more quickly <strong>and</strong> consistently<br />
than h<strong>and</strong> picking. This provides more time to view the<br />
results <strong>and</strong> interpret the data.<br />
Slumping <strong>and</strong> soft sediment deformation are evident in this section of<br />
log. The AutoDip program does a good job of capturing the<br />
changing dips.<br />
Reservoir Evaluation <strong>Services</strong> 2-17<br />
HAL7635
AutoDip Service<br />
AutoDip service uses data from all resistivity buttons—not<br />
just 4, 6, or 8—to more accurately determine dips. By using<br />
more data, more accurate dip readings are possible.<br />
AutoDip service translates the human visual experience of<br />
event correlation into an equation that quantifies visual<br />
recognition to obtain the optimal dip. The self optimizing<br />
algorithmic process¹ operates without the need to adjust<br />
correlation parameters, which can introduce bias into dips or<br />
even hide dips when using traditional methods.<br />
The AutoDip program works equally well in simple bedding<br />
or in more complex bedding environments.<br />
Applications<br />
High-resolution dip detection of EMI, XRMI, <strong>and</strong><br />
OMRI borehole data to help spot “hidden features” in<br />
sedimentary beds <strong>and</strong> laminates<br />
Features<br />
Uses all buttons to compute dips<br />
Uses quality curves to optimize dip selection<br />
Removes user bias in selecting dips<br />
Consistent picks independent of interpreter bias<br />
Output curves that indicate degree of laminations<br />
Output curves that indicate degree of bed contrast<br />
Independence from search angle, correlation length, <strong>and</strong><br />
step length<br />
¹Shin-Ju Ye, et al., Automatic High Resolution Sedimentary<br />
Dip Detection on Borehole Imagery (SPWLA 38th Annual<br />
Logging Symposium, 1997)<br />
Inputs EMI, XRMI, <strong>and</strong> OMRI data set<br />
Outputs Computed dips <strong>and</strong> dip trends<br />
TrendSetter Service<br />
The AutoDip program can generate many dips. The number<br />
of dips is partially determined by dip quality filters. During<br />
the analysis process, it is prudent to look for patterns to help<br />
recognize trends that can impact mapping, offset wells, <strong>and</strong><br />
describe depositional environments <strong>and</strong> structural changes.<br />
TrendSetter service automatically separates dips into<br />
constant, increasing, <strong>and</strong> decreasing categories, making it<br />
easier to visualize changes <strong>and</strong> trends.<br />
TrendSetter service separates the dips from stratigraphic<br />
events such as current bedding, slumps, <strong>and</strong> drapes from the<br />
more constant structural dips, which allows better estimates<br />
of local structural dip.<br />
Applications<br />
Dip trend analysis of EMI, XRMI, <strong>and</strong> OMRI borehole<br />
data to help spot “hidden features” in sedimentary beds<br />
<strong>and</strong> laminates<br />
Features<br />
Automates the selection of dip trends<br />
Provides quality curves used to control grade of trend<br />
Removes scatter from structural dip trend<br />
Identification of other stratigraphic or structural events<br />
when used with other geologic data<br />
A user interface that provides flexibility <strong>and</strong> quality<br />
control<br />
2-18 Reservoir Evaluation <strong>Services</strong>
HAL7642<br />
Trendsetter service eliminates need for h<strong>and</strong>-selecting dip trends.<br />
Reservoir Evaluation <strong>Services</strong> 2-19
ReadyView Open-Hole Imaging System<br />
The ReadyView system provides easy-to-use interactive<br />
software for the analysis of acoustic <strong>and</strong> electrical wellbore<br />
image data. The ReadyView system consists of three<br />
separate applications that provide image <strong>and</strong> dip<br />
interpretation <strong>and</strong> 3D visualization of the wellbore. The<br />
ReadyView system can be used to determine both true <strong>and</strong><br />
apparent bedding dip <strong>and</strong> can also be used to determine the<br />
distribution, orientation, <strong>and</strong> apparent aperture of natural<br />
<strong>and</strong> drilling-induced fractures.<br />
This innovative system uses a customized USB flash drive to<br />
store <strong>and</strong> launch the applications. Performance on the flash<br />
drive is comparable to running on a local hard drive.<br />
It provides unique accessibility to all types of wellbore image<br />
data, along with measurement <strong>and</strong> classification tools<br />
required for borehole breakout, structural, stratigraphic, <strong>and</strong><br />
formation evaluation applications of image analysis.<br />
The software can be modified or augmented to meet the<br />
specific requirements of individual clients.<br />
Features<br />
Runs on Microsoft® Windows® 2000 <strong>and</strong> Microsoft<br />
Windows XP platforms<br />
Works with a wide range of wellbore image data<br />
including third party imaging tools, allowing full 32-bit<br />
RGB color resolution of acoustic <strong>and</strong> electrical image<br />
data<br />
User interface provides a comprehensive set of<br />
sophisticated, interactive measurement tools <strong>and</strong> the<br />
ability to more easily classify <strong>and</strong> describe features<br />
observed in these logs. In particular, the ReadyView<br />
system offers a series of 2D data filters (i.e. Sobel,<br />
Gaussian, Sharpen, Horizontal edge detection) to<br />
enhance the image<br />
Planar features can be displayed in stereographic<br />
projections or rose diagrams; tadpole profiles can be<br />
used to display planar data or wellbore trajectory<br />
St<strong>and</strong>ard log profiles, including gamma <strong>and</strong> resistivity<br />
logs, can be imported <strong>and</strong> displayed as reference logs for<br />
formation interpretation<br />
Menus <strong>and</strong> dialog boxes allow quick scrolling, resizing,<br />
<strong>and</strong> selection of intervals of the data, making image<br />
analysis easy <strong>and</strong> straightforward<br />
Customers can pick <strong>and</strong> interpret their own dips, save<br />
<strong>and</strong> restore their own dip results, <strong>and</strong> export them in a<br />
variety of formats for transfer to other systems including<br />
OpenWorks <strong>and</strong> Microsoft Excel® applications<br />
All image projections <strong>and</strong> data analysis views may be<br />
saved in a variety of raster <strong>and</strong> vector formats for report<br />
generation<br />
Allows wellbore image data to be easily viewed in full<br />
color unwrapped views, polar cross-sections, 3D<br />
cylindrical displays, log profile views, <strong>and</strong> many others<br />
The ReadyView system is also an excellent archival<br />
system for use of the digital image data at a future date<br />
ReadyView System USB Flash Drive<br />
2-20 Reservoir Evaluation <strong>Services</strong>
This example shows a 2D view of image data when launching ReadyView software. From left to right, the first tract<br />
is a compressed image, second tract static image, third tract is depth, fourth tract is a dynamically enhanced image<br />
<strong>and</strong> the right side is a Schmidt plot, image histogram, <strong>and</strong> a dip-azimuth plot.<br />
Reservoir Evaluation <strong>Services</strong> 2-21
Facies Profile<br />
Facies profile is a multi-dimensional, dot-pattern<br />
recognition, clustering method based on nonparametric K—<br />
nearest neighbor <strong>and</strong> graph data representation. The<br />
underlying structure of the data is analyzed, <strong>and</strong> natural data<br />
groups are formed that may have very different densities,<br />
sizes, shapes, <strong>and</strong> relative separations. Facies profile<br />
automatically determines the optimal number of clusters, yet<br />
allows the analyst to control the level of detail actually<br />
needed to define the electro-facies.<br />
Facies profile partitions the reservoir into discrete electrofacies<br />
or flow units. Producing electro-facies is a common<br />
<strong>and</strong> valuable operation performed by oil companies to<br />
discriminate discrete reservoir components. These<br />
components are used to populate reservoir models, flow<br />
simulators, determine porosity/permeability relationships,<br />
<strong>and</strong> describe the reservoir.<br />
The facies profile model can be run with conventional log<br />
data (such as GR, RHOB, or ΔT), NMR data, <strong>and</strong> possibly<br />
other data (not yet tested). A texture profile model based on<br />
the same clustering method has been developed to extract<br />
texture from electric (EMI, XRMI, <strong>and</strong> OMRI data)<br />
image data.<br />
The facies profile analysis shows similarities to a core<br />
description that might be done on a whole core or outcrop.<br />
Grain size, cleanliness, or porosity increase toward the right<br />
<strong>and</strong> changes in facies correspond to different colors <strong>and</strong><br />
patterns. The Facies profile analysis contains automatic<br />
ordering that performs the grain size or porosity function<br />
automatically. The lowest numbered electro-facies has the<br />
smallest grain size or porosity <strong>and</strong> the highest number<br />
electro-facies has the largest grain size or porosity. The<br />
smaller numbered facies would plot farthest to the left, <strong>and</strong><br />
the larger numbered facies would plot farthest to the right.<br />
Applications<br />
Log interpretation that helps define 3D reservoir facies<br />
models describing the distribution of porosity,<br />
permeability, <strong>and</strong> capillary pressure in more detail than<br />
is possible with reflection seismology<br />
Determination of the optimal number of clusters, while<br />
still allowing the analyst to control the level of detail<br />
actually needed to define the electro-facies<br />
Track 4 shows nine electro-facies computed from the GR (Track 1<br />
black) RHOB (Track 3 red) NPHI (Track 3 green) <strong>and</strong> PE (Track 3<br />
magenta). Using these four inputs, facies profile is able to discriminate<br />
differences in the lithology (but not actual lithology) <strong>and</strong> automatically<br />
order them according to increasing grain size or porosity. The EMI<br />
image in Track 1 is provided to show the correlation between the image<br />
<strong>and</strong> electro-facies.<br />
2-22 Reservoir Evaluation <strong>Services</strong><br />
HAL9129
Features<br />
Helps define layering <strong>and</strong> select the best options for<br />
production test interpretation<br />
Integrates geological insight into conventional log<br />
analysis<br />
Automatically clusters <strong>and</strong> orders log data for generating<br />
electro-facies. It processes conventional log data, array<br />
data, such as NMR T2 distribution, image texture<br />
parameters, (texture profile), or any combination of a<br />
wide range of data<br />
Partitions the natural pattern of the data without<br />
requiring the user to give the number of clusters<br />
Inputs<br />
Outputs<br />
Automatically proposes optimal number of clusters.<br />
Clusters are organized in a hierarchical way which can<br />
ease the interpretation<br />
Automatically orders the clusters in log space which uses<br />
coarse-to-fine self-organizing map (CFSOM). This<br />
ordering usually corresponds to the geological facies<br />
evolution order which is particularly important for<br />
assessing geological meaning of each of the facies <strong>and</strong><br />
their vertical sedimentary sequences<br />
All the input curves must have the same step. <strong>Halliburton</strong> recommends placing the input curves to be used in a separate<br />
CLS file because numerous new curves may be generated. The output will have the step of the CLS file.<br />
ALPHA–The higher ALPHA the greater the smoothing. ALPHA can vary from 1 to 500. This parameter has been<br />
optimized <strong>and</strong> it is highly recommended that the user leave it at the default of 10.<br />
K–Another smoothing parameter that can vary from 4 to 20. The higher the number the greater the smoothing. K has also<br />
been optimized <strong>and</strong> it is recommended that the user leave it at the default of 5. The minimum number of electro-facies to<br />
compute. The maximum number of electro-facies to compute. The number of optimal electro-facies models generated by<br />
the program.<br />
EFAC_1, EFAC_2, <strong>and</strong> EFAC_3EFAC—st<strong>and</strong>s for electro-facies. EFAC_1, EFAC_2, etc. are generated electro-facies<br />
model 1, 2, etc. Also see PARAMETER OM.<br />
Gives cluster kernels in log space order (after automatic ordering).<br />
The Kernel Representative Index of each data point.<br />
The Neighboring Index of each data point. It is unique for each data point for a given ALPHA. It measures the local data<br />
density around each point. Higher its value, higher its local density.<br />
The normalized Neighboring Index of each data point within the cluster. Because the cluster member configuration<br />
change with different electrofacies models, NNI is different with different electro-facies models.<br />
Reservoir Evaluation <strong>Services</strong> 2-23
Net2Gross S<strong>and</strong> Count<br />
The preferred approach for determining net pay in laminated<br />
sediments of fluvial <strong>and</strong> turbidite formations is to delineate<br />
s<strong>and</strong> layers from borehole image data. New image<br />
interpretation software, Net2Gross, has been developed to<br />
estimate the s<strong>and</strong> <strong>and</strong> pay counts within the subsurface<br />
sedimentary sequence logged by XRMI X-tended range<br />
imager tool or OMRI oil mud imager tool. The software<br />
exploits the XRMI <strong>and</strong> OMRI tool’s ability to resolve thin<br />
laminations <strong>and</strong> sedimentary structures. It applies threshold<br />
techniques to the pre-processed high resolution XRMI/<br />
OMRI image <strong>and</strong> constructs secondary images for s<strong>and</strong> <strong>and</strong><br />
pay. The analyst retains the flexibility to calibrate these<br />
images to the gamma ray <strong>and</strong> porosity logs using the<br />
cumulative distributions from all the logs to determine valid<br />
threshold values for the images. The software also generates<br />
cumulative s<strong>and</strong> <strong>and</strong> pay counts versus depth. An R-s<strong>and</strong><br />
interpretation is also available by combining image data with<br />
triple combo data. This provides quantitative water<br />
saturation in laminated <strong>and</strong> dispersed shale environments.<br />
The s<strong>and</strong> image is constructed by applying an upper <strong>and</strong><br />
lower threshold to the conductivity amplitude image, after<br />
calibration of this image to the neutron, density <strong>and</strong> gamma<br />
ray logs using the cumulative distributions from the logs <strong>and</strong><br />
image data to determine valid threshold values. Pixels lying<br />
between the lower <strong>and</strong> upper threshold values, <strong>and</strong> greater<br />
than an analyst-specified cutoff are classified as s<strong>and</strong>. S<strong>and</strong><br />
pixels are then upgraded to pay if all of the following<br />
conditions are satisfied: the pixel's image conductivity is<br />
below a specified threshold, porosity greater than a threshold<br />
depth proximal to the pixel exists, <strong>and</strong> deep resistivity greater<br />
than a threshold depth proximal to the pixel exists. Finally,<br />
cumulative s<strong>and</strong> <strong>and</strong> pay counts versus depth are constructed<br />
by simply counting the s<strong>and</strong> <strong>and</strong> pay pixels.<br />
In Track 1, the s<strong>and</strong> image is presented as a binary image,<br />
black for shale <strong>and</strong> white for s<strong>and</strong>. Track 2 presents the pay<br />
image in which s<strong>and</strong>s interpreted to be pay are assigned the<br />
color red.<br />
Features<br />
High-resolution net s<strong>and</strong> <strong>and</strong> net pay images <strong>and</strong> curves<br />
Cumulative net s<strong>and</strong> <strong>and</strong> net pay curve<br />
Logic to prevent interpretation of tight streaks as pay<br />
Interactive histogram based calibration of logging curves<br />
Accurate s<strong>and</strong> <strong>and</strong> net pay counts in laminated<br />
sediments of fluvial <strong>and</strong> turbidite formations<br />
Better agreement between core <strong>and</strong> log, net s<strong>and</strong>,<br />
<strong>and</strong> pay<br />
Combines image data <strong>and</strong> triple combo for an R-s<strong>and</strong><br />
interpretation which provides water saturation for both<br />
laminated <strong>and</strong> dispersed shales<br />
2-24 Reservoir Evaluation <strong>Services</strong>
ImagePerm<br />
ImagePerm is an image based approach providing a highresolution<br />
porosity <strong>and</strong> permeability curve as well as a highresolution<br />
porosity image <strong>and</strong> histograms. In addition, it<br />
provides a high resolution secondary porosity curve, which is<br />
useful for interpretation in the presence of vugs <strong>and</strong><br />
fractures.<br />
The basic approach is to calibrate the image data to image<br />
porosity using filtering techniques. The image data is<br />
averaged over a moving window, <strong>and</strong> a transform is<br />
constructed which calibrates the average image data to<br />
porosity. This transform is then applied to the “pixel-bypixel”<br />
image data <strong>and</strong> a moving adjustment for bias is made.<br />
The final result is shown in Track 5, which shows the EMIP<br />
(or XRMI X-tended range micro-imager tool) porosity<br />
image scaled 0 to .3. Track 4 compares the total porosity<br />
PHIT from the neutron density logs (lazy black curve) with<br />
the image porosity averaged around the borehole (red curve)<br />
at each depth. It can be seen the calibration is correct <strong>and</strong> the<br />
resolution is improved for all the tight, low porosity streaks.<br />
A porosity histogram of the image data as shown in Track 6 is<br />
used to aid in the interpretation <strong>and</strong> detection of vuggy<br />
porosity. Secondary porosity should manifest itself in the<br />
histogram being bimodal with the highest porosity mode<br />
corresponding to secondary porosity. Given each image<br />
porosity histogram, the cumulative distribution can be<br />
computed <strong>and</strong> displayed. In particular, the cumulative<br />
distribution in Track 3 shows in red the variation in porosity<br />
of those 20% of the samples having the highest porosity.<br />
Without any sonic or core data, for illustrative purposes,<br />
these samples were assumed to be secondary porosity. This<br />
constant fraction is converted to a volume <strong>and</strong> displayed in<br />
Track 4 as the gray shaded portion of the display.<br />
This implementation is intended to support a highresolution<br />
prediction of permeability for carbonates. The<br />
Jennings-Lucia model which relates the porosity<br />
permeability transform to rock type has been implemented.<br />
One obtains rock type from looking at core data, or by<br />
calibration to core permeability. Track 2 shows the<br />
permeability from primary porosity as cyan, <strong>and</strong> from<br />
secondary porosity as shaded. The predicted permeability<br />
can either decrease or increase with secondary porosity,<br />
dependent upon the model selected.<br />
Features<br />
High resolution image porosity curve <strong>and</strong> image<br />
High resolution image secondary porosity curve<br />
High resolution micro porosity from MRIL® tool<br />
calibration<br />
Image depth based histograms for rock facies<br />
interpretation<br />
High resolution intergranular permeability<br />
Permeabilty correction for secondary porosity<br />
Rock type based high-resolution permeability<br />
Describes porosity <strong>and</strong> permeability in vuggy carbonate<br />
facies<br />
Helps identify thief zones in vuggy formations, thus<br />
aiding in well completion<br />
Helps identify productive zones in carbonates<br />
Better agreement between core <strong>and</strong> log, permeability,<br />
<strong>and</strong> porosity<br />
Reservoir Evaluation <strong>Services</strong> 2-25
Borehole Geophysics<br />
Wellbore Seismic<br />
High Resolution Seismic Imaging—(Near Offset VSP,<br />
Fixed Offset VSP, Walkaways, 3D VSP, Salt Proximity<br />
Surveys, Microseismic Surveys)<br />
<strong>Halliburton</strong> provides high-resolution images in the vicinity<br />
of the borehole using a number of different techniques<br />
depending on the objectives <strong>and</strong> the geologic environment.<br />
The techniques include vertical incidence vertical seismic<br />
profiles (VIVSP) in deviated wells, salt proximity surveys,<br />
tomographic velocity analysis, fixed offset VSP surveys<br />
(FOVSP), 2D walkaway surveys, 3D VSP, <strong>and</strong> ExactFrac® or<br />
microseismic surveys.<br />
<strong>Halliburton</strong> is an industry leader in providing advanced<br />
source <strong>and</strong> downhole array technologies for borehole<br />
seismic. <strong>Halliburton</strong>’s expertise serves to benefit operators<br />
with reduced rig time <strong>and</strong> improved data quality. Advanced<br />
source <strong>and</strong> receiver technology is crucial towards obtaining a<br />
more accurate <strong>and</strong> comprehensive geological picture of your<br />
well, field, or reservoir.<br />
<strong>Halliburton</strong> can offer custom built solutions for client’s<br />
seismic imaging field needs. For survey planning, we use the<br />
most advanced 3D wavefront modeling software available,<br />
GeoTomo’s VECON software.<br />
Multi-component arrays can be mobilized downhole to more<br />
accurately record true amplitude information of both<br />
compressional <strong>and</strong> shear waves.<br />
Compressional <strong>and</strong> shear images can be used in conjunction<br />
for lithology <strong>and</strong> fluid identification. Surveys can be repeated<br />
for time-lapse 4D views of fluid movements.<br />
Downhole seismic tools can also be used to passively listen to<br />
the reservoir <strong>and</strong> to map fluid movements, fault reactivation,<br />
or active fracture monitoring.<br />
A full array of tools is available for analyzing high resolution<br />
seismic data for reservoir imaging. <strong>Halliburton</strong> offers<br />
advanced pre-processing, including multi-component<br />
wavefield separation <strong>and</strong> final imaging using pre-stack depth<br />
migration (PSDM).<br />
High Resolution Seismic Imaging Features<br />
Generation of high-resolution multiple free images<br />
Mapping of steep structures (such as salt flanks)<br />
Detailed velocity cubes in areas of laterally changing<br />
velocity (shallow gas, permafrost, salt, etc.)<br />
Map structure, stratigraphy, lithology, <strong>and</strong> fluids with<br />
higher resolution <strong>and</strong> confidence than can be obtained<br />
with surface seismic<br />
Improve a poor data quality area or overcome no-data<br />
areas<br />
High Resolution Seismic Imaging Applications<br />
Profiling salt dome flanks<br />
Detecting natural fractures<br />
Enhanced seismic velocity analysis<br />
Primary seismic reflector identification<br />
Porosity <strong>and</strong> permeability estimation<br />
Anisotropy determination<br />
AVO analysis<br />
Determine height, length, <strong>and</strong> width of well frac or<br />
stimulation process<br />
Associated Answer <strong>Products</strong><br />
Vertical incidence VSP<br />
Synthetic seismogram<br />
FWS full wave sonic processing<br />
ExactFrac® services<br />
2-26 Reservoir Evaluation <strong>Services</strong>
Reservoir Geophysics<br />
Long Array Multi-Component Acquisition Tools<br />
<strong>Halliburton</strong> offers survey planning, data acquisition, <strong>and</strong><br />
data processing using multi-component long seismic arrays.<br />
Each tool combines advanced-source technology with<br />
industry leading multi-component <strong>and</strong> anisotropic<br />
migration software for a complete package of advanced<br />
custom designed reservoir imaging systems. Systems include<br />
the GeoChain VSP downhole receiver array.<br />
GeoChain VSP Downhole Receiver Array<br />
The GeoChain vertical seismic profile (VSP) array is<br />
designed for large borehole imaging surveys <strong>and</strong> can be used<br />
in open <strong>and</strong> cased holes with st<strong>and</strong>ard seven-conductor cable<br />
even in deep <strong>and</strong> hostile environments.<br />
GeoChain VSP Receiver Array Features<br />
Based on the proven ASR-1 downhole geophone<br />
Can be used in wells up to 25,000 psi <strong>and</strong> with hole sizes<br />
from 3.5-in. to 22-in.<br />
Unique ACS active cooling system allows continuous<br />
operation up to 356°F (180°C)<br />
Up to 42 satellites can be used in the array with a<br />
maximum tool spacing of 200 ft<br />
All satellite locking arms open <strong>and</strong> close simultaneously,<br />
<strong>and</strong> the entire string can lock into a 9.625-in. well in only<br />
30 seconds<br />
Can be run in the following configurations:<br />
No. of Tools Sample Rate<br />
5 1/2 ms<br />
10 1 ms<br />
21 2 ms<br />
26 2.5 ms<br />
32 3 ms<br />
42 4 ms<br />
Associated Answer <strong>Products</strong><br />
3D VSP imaging<br />
2D VSP imaging<br />
Interwell imaging<br />
ExactFrac® (microseismic) services<br />
Synthetic Seismic <strong>and</strong> Sonic Log Calibration<br />
The synthetic seismogram obtains an accurate tie between<br />
well logs measured in depth <strong>and</strong> the surface seismic image<br />
measured in two-way time. Correlation between logs <strong>and</strong><br />
seismic is important to verify interpreted horizons <strong>and</strong> to<br />
help determine the true phase of the surface seismic<br />
(important for advanced lithologic <strong>and</strong> fluid interpretations<br />
from seismic data).<br />
An accurate synthetic depends on sonic log calibration using<br />
data from a vertical seismic profile (VSP) or check shot<br />
survey. This calibration is necessary for a number of reasons<br />
such as:<br />
Sonic log <strong>and</strong> surface seismic are measured at different<br />
frequencies (dispersion)<br />
Sonic log <strong>and</strong> surface seismic can measure different rock<br />
<strong>and</strong> fluid volumes (fluid differences, invaded zones,<br />
damaged borehole, non-vertical ray paths, etc.)<br />
Calibration of the sonic log includes an analysis of the data to<br />
determine the cause of the differences (drift) between the<br />
sonic <strong>and</strong> the check shots.<br />
Depending on the cause of the drift, different methods of<br />
correction are used. The corrected sonic log is converted to<br />
interval velocity. Acoustic impedance is calculated using the<br />
corrected velocity log <strong>and</strong> the bulk density. Changes in<br />
acoustic impedance are used to create a reflection coefficient<br />
log, which is subsequently convolved with a desired wavelet<br />
to create a synthetic seismic trace.<br />
Recording of a shear sonic log or calculation of a synthetic<br />
shear log allows calculation of a 2D synthetic to analyze or<br />
predict AVO effects on the surface seismic. Perturbation of<br />
the rock parameters also allows study of the effects of fluid<br />
<strong>and</strong> lithology changes on the seismic character.<br />
Synthetic Seismic Features<br />
Helps promote accurate tie between well logs <strong>and</strong> surface<br />
seismic including phase determination<br />
Allows identification of multiples on the surface seismic<br />
Allows study of fluid <strong>and</strong> lithology effects on the seismic<br />
character<br />
Associated Answer <strong>Products</strong><br />
Vertical incidence VSP<br />
High resolution seismic imaging (walkaway, fixed offset,<br />
3D VSP, salt proximity, AVO Studies)<br />
FWS full wave sonic processing<br />
Reservoir Evaluation <strong>Services</strong> 2-27
Vertical Incidence Vertical Seismic Profiling (VIVSP) Analysis<br />
The VIVSP analysis is a downhole seismic survey with the<br />
surface source positioned vertically above the geophones<br />
anchored in the well. In a vertical well, it is known as a zero<br />
offset VSP (ZOVSP) with the source positioned in a single<br />
location near the wellhead. In highly deviated wells, the<br />
source is moved along with the downhole geophone tool to<br />
keep the source vertically positioned above the geophone<br />
tool at each level.<br />
VIVSP analysis is useful for facilitating more accurate timedepth<br />
correlation between your well logs <strong>and</strong> your surface<br />
seismic. It is also useful for determining the phase of your<br />
surface seismic <strong>and</strong> for identifying multiples.<br />
VIVSP data provides an indispensable bridge between sonic<br />
log data <strong>and</strong> surface seismic data. In areas where it is difficult<br />
to obtain a good tie between the synthetic <strong>and</strong> the surface<br />
seismic, the VIVSP can be helpful to identify <strong>and</strong> resolve the<br />
differences.<br />
VIVSP is also very useful for predicting lithology, fluids, <strong>and</strong><br />
pore pressure ahead of the bit. Velocity trends that are useful<br />
for predicting pore pressure are calibrated at the well.<br />
VIVSP data is typically higher frequency than the surface<br />
seismic <strong>and</strong> can be used to better underst<strong>and</strong> the reflectivity<br />
seen in the surface seismic.<br />
VIVSP data can be useful for computing the dip of the<br />
reflecting horizons in the vicinity of the borehole.<br />
This can be used to confirm dips seen on dipmeter tools <strong>and</strong><br />
help project these dips away from the well.<br />
In deviated wells, the VIVSP also delivers a high resolution<br />
2D image beneath the wellbore. This image is typically<br />
higher frequency than the surface seismic, multiple free, <strong>and</strong><br />
tied directly to the wellbore in depth.<br />
<strong>Halliburton</strong> uses advanced proprietary software to h<strong>and</strong>le<br />
VSPs in the most dem<strong>and</strong>ing geologic environments<br />
(advanced editing, multi-component wavefield separation,<br />
interpolation, deconvolution, <strong>and</strong> migration tools).<br />
VSP software <strong>and</strong> processing can be used in the field, in a<br />
computing center linked to the wellsite, or in the client<br />
offices for special projects.<br />
VSP acquisition teams utilize customized energy sources <strong>and</strong><br />
the most advanced seismic tools available to record high-<br />
quality seismic data. The rugged, computerized logging<br />
systems precisely position the geophone tool in the well,<br />
properly synchronize the energy sources, <strong>and</strong> accurately<br />
transfer the measured data to the surface. The data obtained<br />
from VSPs provide extremely important information for<br />
enhancing <strong>and</strong> supplementing surface seismic data.<br />
VIVSP Features<br />
Allows detailed analysis of the downgoing <strong>and</strong> upgoing<br />
wavefield<br />
Real seismic trace rather than synthetic for log seismic<br />
correlation<br />
Provides detailed velocity analysis<br />
VSP Applications<br />
Direct correlation between surface seismic data <strong>and</strong> logs<br />
recorded in depth<br />
Calibrate wireline sonic data for correlating synthetic<br />
seismograms with conventional seismograms<br />
Mapping geologic structure in the vicinity of the wellbore<br />
Predict stratigraphy, lithology, <strong>and</strong> structure ahead of the<br />
drill bit to help save drilling time <strong>and</strong> costs<br />
Improve poor data-quality area or overcome no-data area<br />
Helps profile salt dome flanks<br />
Helps detect natural fractures<br />
Aids seismic identification of lithology<br />
Prospect delineation<br />
Enhanced seismic velocity analysis<br />
Primary seismic reflector identification<br />
Analyze multiple patterns<br />
Deconvolution operator for surface seismic data<br />
processing<br />
Porosity <strong>and</strong> permeability estimation<br />
2D <strong>and</strong> 3D stratigraphic <strong>and</strong> structural imaging<br />
Helps locate overthrust granite/sediment interface<br />
AVO analysis<br />
Associated Answer <strong>Products</strong><br />
Synthetic seismogram<br />
High resolution seismic imaging (walkaway, fixed offset,<br />
ocean bottom cable, salt proximity, AVO studies)<br />
FWS full wave sonic processing<br />
2-28 Reservoir Evaluation <strong>Services</strong>
ExactFrac ® <strong>Services</strong><br />
<strong>Halliburton</strong> eases frac modeling concerns by taking a fullservice<br />
approach to logging, offering both dipole sonic <strong>and</strong><br />
borehole seismic services. To give engineers the answers they<br />
require, our microseismic techniques provide real-time<br />
assessments of fracturing processes using two wells:<br />
A stimulation well where actual frac jobs are under way<br />
A monitor well equipped with a downhole geophone<br />
tool array with multiple sensors<br />
These microseismic techniques provide accurate information<br />
on the length, height, <strong>and</strong> distance of the frac being<br />
generated in the formation <strong>and</strong> can dramatically optimize<br />
the placement of future wells.<br />
ExactFrac <strong>Services</strong> Features<br />
Allows operators to optimize drilling program in field<br />
Improves later frac jobs (only zone you need to frac)<br />
Minimizes uncertainty in your fracturing program<br />
Reservoir Evaluation <strong>Services</strong> 2-29
Acoustics <strong>and</strong> Rock Properties<br />
Anisotropy Analysis<br />
Sonic anisotropy data—the directional sound attenuating<br />
characteristics of the reservoir—is used to improve the timeto-depth<br />
correlation since both fast <strong>and</strong> slow shear waves<br />
may be present. It also helps to develop synthetic<br />
seismograms using both the fast <strong>and</strong> slow shear wave <strong>and</strong><br />
their orientation to improve 3D seismic analysis <strong>and</strong> future<br />
seismic acquisition.<br />
The waveform data from the WaveSonic® crossed dipole<br />
sonic tool is analyzed with the anisotropy waveform<br />
processing model to obtain the fast <strong>and</strong> slow shear wave<br />
travel times <strong>and</strong> their orientation in the formation. The<br />
anisotropy analysis processing engine is a simultaneous<br />
inversion technique which uses all 64 dipole waveforms,<br />
from the in-line <strong>and</strong> crossed-line transmitter-receiver arrays.<br />
The objective function includes all combinations of all<br />
waveforms, so it maximizes the redundancy which improves<br />
the robustness of the processing method.<br />
The minimum <strong>and</strong> maximum principal stresses <strong>and</strong> stress<br />
field orientation are calculated by combining oriented<br />
slowness data with overburden <strong>and</strong> pore pressure data. This<br />
information is vital for geomechanical analysis, wellbore<br />
stability, <strong>and</strong> production enhancement treatment design.<br />
Sonic anisotropy <strong>and</strong> the orientation of the anisotropy can be<br />
used to determine the orientation of natural fractures. Sonic<br />
attributes such as P-wave slowness, fast, <strong>and</strong> slow shear wave<br />
travel time, can be used for identification of compressive<br />
fluids in the pore space. This allows planning of the best<br />
completion method <strong>and</strong> builds reservoir underst<strong>and</strong>ing to be<br />
applied to the next well.<br />
Applications<br />
Analyze WaveSonic tool waveform data to identify fast<br />
<strong>and</strong> slow shear wave travel times <strong>and</strong> their orientation in<br />
the formation<br />
Develop synthetic seismograms to improve 3D seismic<br />
analysis <strong>and</strong> future seismic acquisition<br />
Identification of compressive fluids in the pore space to<br />
maximize completion planning<br />
This is an example of fracture anisotropy. The fast <strong>and</strong> slow shear wave<br />
travel times are presented in Track 3. The azimuth of the fast shear wave<br />
is presented in Track 2 along with its uncertainty. The percent<br />
anisotropy is presented in Track 4, <strong>and</strong> shaded when the anisotropy is<br />
greater than 5%. The anisotropy is also presented in an image on the far<br />
right-h<strong>and</strong> track. North is on the right <strong>and</strong> left-h<strong>and</strong> edges of the plot<br />
<strong>and</strong> South is in the middle. The color intensity is proportional with the<br />
magnitude of the anisotropy. The rose plots in Track 4 shows the change<br />
in azimuth of the anisotropy. The energy ratio curves shaded in Track 1<br />
identify the anisotropy as being a result of natural fractures.<br />
2-30 Reservoir Evaluation <strong>Services</strong><br />
HAL9130
Features<br />
WaveSonic® tool provides simultaneous monopole <strong>and</strong><br />
crossed dipole sonic information<br />
The low frequency flexural wave travels at the true shear<br />
slowness of the formation—dispersion corrections for<br />
shear wave slowness are not required<br />
A low frequency monopole source is utilized, so the<br />
P-wave <strong>and</strong> flexural wave data have similar depths of<br />
investigations well beyond any near-wellbore alteration<br />
The wellsite products from the WaveSonic tool are the<br />
X-X <strong>and</strong> Y-Y flexural (shear) wave slowness (time travel)<br />
<strong>and</strong> the monopole P-wave slowness<br />
Depth shifting of the waveform data is not required since<br />
the X-X <strong>and</strong> Y-Y depth dipole transmitters are on a<br />
common depth<br />
Inputs<br />
Outputs<br />
Associated Answer <strong>Products</strong><br />
RockXpert analysis–s<strong>and</strong> production <strong>and</strong> fracture<br />
strength analysis<br />
FracXpert analysis–fracture stimulation zoning<br />
analysis<br />
Navigation data, all in-line <strong>and</strong> cross-line dipole waveforms, processing window starting time <strong>and</strong> processing window<br />
width<br />
Fast <strong>and</strong> slow shear wave travel time <strong>and</strong> their corresponding orientations, anisotropy (as curve <strong>and</strong> image), rose plots of<br />
azimuth of the fast shear<br />
Reservoir Evaluation <strong>Services</strong> 2-31
RockXpert2 Analysis<br />
Knowledge of rock properties <strong>and</strong> borehole stresses as<br />
provided by <strong>Halliburton</strong>’s RockXpert2 analysis allow<br />
drilling, completion, <strong>and</strong> stimulation optimization. It has<br />
been estimated that borehole stability problems cost the oil<br />
industry more than $2 billion annually.<br />
Sloughing or collapsed wellbores can stick downhole tools<br />
<strong>and</strong> tubulars, which lead to lost rig time, expensive fishing<br />
jobs, side-tracking, or even well ab<strong>and</strong>onment. Inadvertent<br />
fracturing of weak formations can result in lost circulation,<br />
<strong>and</strong> improperly planned hydraulic fracturing operations can<br />
give disappointing production results.<br />
RockXpert2 analysis provides critical information for<br />
designing fracturing programs, planning drilling operations,<br />
<strong>and</strong> evaluating s<strong>and</strong>ing potential. The RockXpert2 program<br />
uses well log data to calculate rock mechanical properties <strong>and</strong><br />
borehole stresses.<br />
These rock mechanical properties include Poisson’s Ratio,<br />
Young’s Modulus, shear modulus, <strong>and</strong> bulk modulus. The<br />
stresses include axial, tangential, radial, maximum<br />
horizontal, <strong>and</strong> minimum horizontal.<br />
The use of RockXpert2 analysis allows the customer to drill,<br />
complete, stimulate, <strong>and</strong> produce the well at the most<br />
economical cost. Wells can be drilled to avoid geomechanical<br />
problems including lost circulation zones, s<strong>and</strong>ing potential,<br />
<strong>and</strong> borehole collapse, but the well can be completed,<br />
stimulated, <strong>and</strong> produced without causing tensile, shear, or<br />
cohesive failure, <strong>and</strong> pore collapse.<br />
Applications<br />
Reduce the risk of losses from borehole instability<br />
Determines optimum mud weights required to prevent<br />
s<strong>and</strong>ing <strong>and</strong> fracturing during drilling operations<br />
Evaluate a well's s<strong>and</strong>ing potential to determine whether<br />
gravel packs or frac packs are necessary<br />
7 9 11 13 15 17 19 21 23 25<br />
Mud Weight - Pounds per Gallon<br />
At any specified point along a proposed or existing well path,<br />
RockXpert2 analysis can identify stable borehole conditions as a<br />
function of mud weight <strong>and</strong> borehole deviation.<br />
RockXpert2 logs indicate the safe mud weight range to provide s<strong>and</strong>ing<br />
<strong>and</strong> formation breakdown, as shown in Track 2. The logs also include<br />
gamma <strong>and</strong> caliper curves in Track 1, predicted maximum borehole<br />
deviation in Track 3, <strong>and</strong> lithology information in Track 4.<br />
2-32 Reservoir Evaluation <strong>Services</strong><br />
HAL951<br />
HAL157<br />
Borehole Deviation<br />
90<br />
80<br />
70<br />
60<br />
50<br />
40<br />
30<br />
20<br />
10<br />
0<br />
5<br />
Shear<br />
Failure<br />
Stable<br />
Borehole<br />
Tensile<br />
Failure
Features<br />
Provides valuable input to fracture-design programs that<br />
predict fracture geometry <strong>and</strong> that help select fracturing<br />
fluids, proppants, <strong>and</strong> pumping schedules<br />
Determines the mud weights required to prevent s<strong>and</strong>ing<br />
<strong>and</strong> fracturing during drilling<br />
Provides optimal direction in which to drill deviated,<br />
horizontal, <strong>and</strong> extended-reach wells to maximize<br />
borehole stability <strong>and</strong> increase the effectiveness of<br />
subsequent hydraulic fracturing<br />
Assists in evaluating a well’s s<strong>and</strong>ing potential to<br />
determine whether a gravel pack or frac pack may be<br />
necessary to help maintain production at optimal levels<br />
Helps assist in determining the maximum amount of<br />
drawdown to eliminate both s<strong>and</strong>ing potential <strong>and</strong><br />
borehole collapse<br />
Computations use data from continuous well logs rather<br />
than from core or microfrac measurements made at<br />
discrete points<br />
Computes stress magnitude <strong>and</strong> takes into account<br />
borehole orientation relative to stress-field orientation<br />
Results can be input directly into <strong>Halliburton</strong>’s<br />
FracXpert program<br />
Results can be normalized to core-analysis results.<br />
<strong>Halliburton</strong> maintains an advanced rock mechanics<br />
laboratory that provides comprehensive core analysis<br />
Inputs Compressional wave travel time, ΔT C, shear wave travel time, ΔT S, bulk density, VSH, pressure gradients<br />
Outputs Poisson’s Ratio, Young’s Modulus, shear modulus, bulk modulus, fracture pressure, collapse pressure<br />
Reservoir Evaluation <strong>Services</strong> 2-33
FracXpert Analysis<br />
FracXpert analysis provides total data integration for 3Dfracture<br />
modeling. The FracXpert log provides automatic<br />
zoning based upon stress contrasts <strong>and</strong> averages the design<br />
parameters for each zone. It includes a presentation of log<br />
data that includes lithology, porosity, saturations,<br />
permeability index, <strong>and</strong> borehole stress information.<br />
FracXpert analysis provides linkages between the actual well<br />
properties <strong>and</strong> the fracturing design models. The automatic<br />
zoning removes possible design errors based on incorrect<br />
observations by the stimulation design engineer. This<br />
extremely fast process allows different scenarios to be<br />
analyzed <strong>and</strong> processed in both FracXpert analysis <strong>and</strong> the<br />
fracture modeling programs. After the stimulation is<br />
performed, modifications can be made to both models to<br />
accurately account for the stimulation response.<br />
Early frac design models did not include important design<br />
criteria such as pumping rates, fluid efficiencies, or treatment<br />
volumes. The FracPro program incorporates all these<br />
additional job parameters to accurately model, optimize, <strong>and</strong><br />
execute frac operations.<br />
The rock mechanical data is taken from the results of<br />
formation strength-borehole stability analysis programs such<br />
as RockXpert2 analysis. The analyst needs to run a<br />
volumetric log analysis model to find both the shale volume<br />
needed for the rock mechanical programs <strong>and</strong> to compute<br />
the permeability.<br />
FracXpert analysis differentiates itself from other zoning type<br />
logs which usually do not have adequate log processing<br />
capabilities. In that case, the log analysis or the picking of the<br />
relevant logging parameters is still done by h<strong>and</strong>, <strong>and</strong> the<br />
quality depends heavily on the experience of the stimulation<br />
design engineer. Several consultants have a similar approach<br />
to hydraulic fracture design.<br />
The depth track provides zonal numbering, pay <strong>and</strong> bad hole flags,<br />
perforations, <strong>and</strong> perforation numbering. The zonal numbers are<br />
assigned to the selected zones as determined by the zoning process based<br />
on fracture tensile pressure. Track 1 contains CORAL lithology track<br />
consisting of shale, dolomite, limestone, s<strong>and</strong>, <strong>and</strong> porosity. Track 2<br />
presents that calculated water saturation. Track 3 displays CORAL<br />
analysis results that include effective porosity, water, <strong>and</strong> hydrocarbons.<br />
Track 4 presents the fracture tensile pressure <strong>and</strong> gradient from<br />
RockXpert2 analysis. Track 5 provides five different flow calculations to<br />
help determine the economic potential of each zone. Track 5 also displays<br />
two normalized curves that help interpret zones of interest: permeability<br />
feet (NKH) <strong>and</strong> porosity feet (NPORH). Both are normalized from 0 to 1<br />
over the entire well.<br />
2-34 Reservoir Evaluation <strong>Services</strong><br />
HAL9131
Applications<br />
Total data integration for 3D fracture modeling<br />
Log processing using automatic zoning<br />
Features<br />
Automatic zoning helps define different layers within the<br />
formation for more accurate <strong>and</strong> consistent results<br />
without bias of the user<br />
Outputs include a well log plot, tabular listings, <strong>and</strong> an<br />
ASCII data file for input to 3D models<br />
Economic models <strong>and</strong> reservoir simulation reports are<br />
generated for accurate comparisons<br />
Stress information is gathered from FWS full wave<br />
sonic or dipole sonic logs<br />
Software can use permeability from conventional<br />
saturation/effective porosity relationships or from<br />
nuclear magnetic resonance logs<br />
Inputs Poisson's Ratio, Young's Modulus, minimum horizontal stress, permeability, pore pressure, <strong>and</strong> shale volume<br />
Outputs<br />
Automatic zoned averaging of the rock mechanical properties <strong>and</strong> volumetric data. Text files for simulators <strong>and</strong><br />
stimulation programs.<br />
Reservoir Evaluation <strong>Services</strong> 2-35
AcidXpert Analysis<br />
AcidXpert analysis aids in the design of stimulation<br />
treatments on carbonate rocks. The AcidXpert process<br />
provides a st<strong>and</strong>ard log presentation <strong>and</strong> associated text files<br />
that allow importation into other analysis packages.<br />
The success of matrix acidizing treatments depends on the<br />
placement of acid for efficiently removing near-wellbore<br />
formation damage. The type <strong>and</strong> composition of the acid is<br />
selected due to the rock matrix involved. The acid should be<br />
placed so that all potentially productive intervals accept a<br />
sufficient quantity of the total acid volume. If significant<br />
permeability or formation damage variations are present in<br />
the interval to be treated, acid will enter the zones with the<br />
highest permeability or least formation damage, leaving little<br />
acid to treat what may be the most productive zones.<br />
AcidXpert analysis is a process to collect <strong>and</strong> interpret the<br />
available data to maximize the stimulation effort. AcidXpert<br />
analysis provides answers for the following questions:<br />
With a complex lithology, how detrimental are the<br />
carbonate mineralogies to production enhancement?<br />
Is there a wide variance in the rock mineralogies?<br />
Is there sufficient permeability for the well to flow?<br />
Are natural fractures present, <strong>and</strong> do they intersect the<br />
wellbore?<br />
What is a reasonable expectation for production?<br />
How should the stimulation treatment be modified for<br />
specific scenarios?<br />
What factors require attention? Is the right information<br />
available to make this judgement?<br />
AcidXpert analysis automatic zoning provides a superior<br />
method for stimulation evaluation. Additionally, generated<br />
text files allow easy input into several analysis models<br />
including reservoir stimulation, economic, <strong>and</strong> stimulation<br />
design.<br />
There might be different stimulation scenarios depending<br />
upon the log data, <strong>and</strong> AcidXpert analysis allows these<br />
scenarios to be modeled efficiently <strong>and</strong> effectively. The<br />
minimal data required by AcidXpert analysis includes<br />
resistivity, density, <strong>and</strong> neutron log data along with<br />
volumetrics. Additional processing can be used if FWS full<br />
wave sonic logs, MRIL®, <strong>and</strong> imaging logs are available.<br />
Matrix acidizing requires basic triple combo data <strong>and</strong><br />
volumetrics<br />
Acid fracturing requires the components necessary for<br />
Matrix acidizing plus FWS full wave sonic tool data<br />
StiMRIL process requires the components of acid<br />
fracturing plus MRIL® data<br />
Within the depth track on the left side of the log are perforations,<br />
perforation number, a bad-hole indicator, pay flag, <strong>and</strong> the numbering<br />
assigned to the selected zones as determined by the zoning process. The<br />
red lines across all the tracks delineate the zones that were chosen based<br />
upon solubility. Track 1 contains gamma ray <strong>and</strong> temperature. Track 2 is<br />
the solubility curve, a sum of the limestone <strong>and</strong> dolomite minerals on a<br />
depth-by-depth basis. The pink shading indicates zones that could<br />
effectively be treated by acid stimulation. Track 3 provides lithology data<br />
that was generated by CORAL analysis. Track 4 presents that<br />
calculated water saturation. Track 5 displays analysis results that include<br />
effective porosity, water, <strong>and</strong> hydrocarbons. Track 6 presents a calculated<br />
permeability <strong>and</strong> effective water permeability.<br />
2-36 Reservoir Evaluation <strong>Services</strong><br />
HAL9132
Applications<br />
Design of stimulation treatments on carbonate rocks<br />
Import st<strong>and</strong>ard log presentation <strong>and</strong> associated text<br />
files into other analysis packages<br />
Collect <strong>and</strong> interpret available data for stimulation<br />
treatments<br />
Inputs<br />
Features<br />
Automatic zoning based on the rock matrix, fracture<br />
initiation pressures, or permeability<br />
Part of a comprehensive approach to acidization that<br />
improves well performance<br />
The use of the automatically generated text files allows<br />
easy linkages to reservoir stimulation, reservoir<br />
performance, <strong>and</strong> economic models<br />
St<strong>and</strong>ard processed volumetric data including porosity, matrix lithology, permeability, <strong>and</strong> water saturation. Additional<br />
inputs can include sonic <strong>and</strong> MRIL ® data.<br />
Outputs St<strong>and</strong>ard zoned log presentation along with automatically generated text reports.<br />
Reservoir Evaluation <strong>Services</strong> 2-37
Reservoir <strong>and</strong> Production Engineering<br />
Reservoir Testing Studio<br />
RTS Reservoir Testing Studio<br />
RTS reservoir testing studio provides real-time analysis of<br />
data while it is being acquired to improve test quality <strong>and</strong><br />
shorten rig time. RTS analysis features <strong>Halliburton</strong>'s<br />
proprietary Exact <strong>and</strong> FasTest® analysis service techniques<br />
as well as conventional Horner (radial) <strong>and</strong> spherical time<br />
plot well test routines. RTS studio is designed to work with<br />
<strong>Halliburton</strong>'s InSite® real-time data management <strong>and</strong><br />
distribution system. The InSite Anywhere® option provides<br />
real-time access to RTS analysis plots, from anywhere <strong>and</strong> at<br />
anytime, with a st<strong>and</strong>ard internet connection. A report<br />
generator compiles the pressure transient analysis into<br />
reports that contain summary tables, gradient plots, <strong>and</strong> all<br />
the analysis plots. The summary tables can be exported to<br />
Microsoft® Excel® spreadsheets or Microsoft Word® tables.<br />
Applications<br />
Analysis of drawdowns <strong>and</strong> buildup pressure transients<br />
Determine pressure transient flow regime (spherical or<br />
radial)<br />
Summary tables of test results<br />
Pressure gradient analysis plots<br />
Sample PVT closed chamber testing<br />
Features<br />
QC pressure transient data<br />
Makes data selections for gradient analysis<br />
Provides project formation pressure (P*)<br />
Estimates mobility (1,000 - 0.001 md/cp)<br />
Estimates of anisotropy (kv/kh) Documents results in a final report<br />
The following plots <strong>and</strong> analysis techniques are available<br />
with RTS analysis.<br />
Pressure Time Plot<br />
The pressure time plot is the primary display that documents<br />
the data to be analyzed. The data selections made are later<br />
summarized in tabular form. From these data selections, an<br />
initial estimate of the formation mobility is made using the<br />
raw data (M raw drawdown mobility). The pressure time plot<br />
also includes a pressure stability plot with a wrapping scale<br />
from 0 to 10 or 0 to 1 psi so that the pressure can be observed<br />
on an exp<strong>and</strong>ed scale.<br />
RTS analysis pressure time plot is used to make data selections, which<br />
are documented in summary tables. Additionally, the results are used to<br />
create gradient plots <strong>and</strong> calculate the drawdown mobility (md/cp).<br />
2-38 Reservoir Evaluation <strong>Services</strong>
Exact Buildup Analysis<br />
The Exact buildup analysis can be used to estimate<br />
spherical mobility (M s Ex) <strong>and</strong> formation pressure (P* Ex)<br />
over a wide range of mobilities (i.e., 0.001 to more than<br />
1000 md/cp). Conventional methods of analysis use late time<br />
data which requires pressures to stabilize after storage effects<br />
have dissipated. For low mobility zones (less than<br />
1 mDarcy/cp), this can require long buildup times, but Exact<br />
analysis can match the early time data thus shortening the<br />
test time required. In higher mobility, Exact analysis can also<br />
be used to provide accurate estimates of mobility <strong>and</strong><br />
formation pressure.<br />
Exact Anisotropy Analysis Plot<br />
The Exact anisotropy plot is a buildup analysis method used<br />
for a vertical interference testing (VIT). The pressure<br />
recorded at a vertical monitoring probe is combined with the<br />
source (either probe or straddle packer) buildup analysis to<br />
determine the horizontal mobility (M hrz ex ) <strong>and</strong> the ration of<br />
vertical to horizontal mobility, Aniso (k v /k h ) ex .<br />
The RTS Exact analysis plot is a priority analysis technique designed<br />
to be used over the entire range of operation for formation testers. In<br />
addition to estimating the mobility from the buildup, the formation<br />
pressure can be estimated before the shut-in pressure is established,<br />
saving rig time.<br />
Example of an Exact Anisotropy Analysis Plot<br />
Reservoir Evaluation <strong>Services</strong> 2-39
FasTest ® Buildup Analysis<br />
FasTest® buildup analysis can be used when mobility is above<br />
1 mDarcy/cp. Originally developed for well test surge or<br />
impulse testing analysis, it is also well suited for SFT <strong>and</strong><br />
RDT tool buildup analysis. FasTest analysis is considered<br />
more reliable than traditional methods because it does not<br />
depend on an accurate estimate of the drawdown period or<br />
rate. Therefore, it is ideal for buildups where the sample<br />
chamber is used to create the pressure impulse. FasTest<br />
analysis can:<br />
Save rig time by terminating tests as soon as a sufficient<br />
amount of data is obtained<br />
Analyze sample chamber pressure pulse to determine<br />
permeabilities up to at least 1 Darcy (Mfast ) for both<br />
spherical or radial flow regimes<br />
Determine flowline storage effects on measured pressure<br />
Provide accurate calculated s<strong>and</strong>face pressure estimates<br />
(P* Fast)<br />
Horner Time Plots<br />
Horner time plots are the traditional technique for analyzing<br />
pressure transient analysis data. Both spherical <strong>and</strong> radial<br />
time domains are available with the projected formation<br />
pressure (P*), Horner mobility being determined from the<br />
slope of a line formed from a regression of the data on a<br />
radial or spherical time plot. Horner interpretation for<br />
wireline testers is generally used for zones with mobilities<br />
above 1md/cp.<br />
RTS FasTest® analysis service plot is used for buildup analysis in more<br />
permeable zones (i.e., > 1md/cp). The FasTest analysis is very flexible <strong>and</strong><br />
can be used for pretests as well as sample chamber surge tests. Either<br />
spherical or radial flow regimes can be used.<br />
RTS analysis Horner plot offers a traditional method of analyzing<br />
pretest buildups. Either spherical or radial flow regimes can be used.<br />
2-40 Reservoir Evaluation <strong>Services</strong>
Log-Log Derivative Analysis Plot<br />
This plot verifies the flow regime <strong>and</strong> data quality of the<br />
pressure transient. The FasTest® analysis service derivative<br />
<strong>and</strong> pressure differential of the buildup data is presented in<br />
this plot. Either a spherical time or conventional radial time<br />
derivative can be chosen so that a stable horizontal line<br />
represents infinitely acting flow for either regime.<br />
RTS analysis log-log derivative plot is based on the FasTest® analysis service derivative <strong>and</strong> is used to verify<br />
the flow regime of buildups <strong>and</strong> evaluate the quality of the pressure transient.<br />
Reservoir Evaluation <strong>Services</strong> 2-41<br />
M<br />
spher<br />
M<br />
1<br />
1.<br />
5<br />
⎛<br />
⎞<br />
⎜<br />
1.<br />
5<br />
⎟<br />
⎛1013<br />
⎞⎜<br />
Vo<br />
φ c f<br />
= ⎜ ⎟<br />
⎟<br />
⎝ 4π<br />
⎠⎜<br />
⎟<br />
2.<br />
5⎛<br />
dp ⎞<br />
⎜ t ⎜ ⎟ ⎟<br />
⎝ ⎝ dt ⎠ ⎠<br />
radial<br />
⎛ ⎞<br />
⎜ ⎟<br />
⎛1013<br />
⎞⎜<br />
Vo<br />
= ⎜ ⎟<br />
⎟<br />
⎝ 4π<br />
⎠⎜<br />
⎛ ⎞ ⎟<br />
2 dp<br />
⎜ ht<br />
⎜ ⎟ ⎟<br />
⎝ ⎝ dt ⎠ ⎠
PVT Analysis<br />
A PVT plot is available for the RDT reservoir description<br />
tool service. This is a closed chamber in-situ sample analysis<br />
test that is performed automatically during the pumping<br />
process <strong>and</strong> after a sample is taken. The bubblepoint <strong>and</strong><br />
fluid compressibility is determined.<br />
Formation Test Summary Program (FTS)<br />
The FTS program compiles RTS pressure test analysis data<br />
<strong>and</strong> creates gradient plots <strong>and</strong> summary tables. When<br />
selections are made from real-time data, they are<br />
automatically added to the gradient analysis. This allows<br />
multiple zones, gradients, <strong>and</strong> contacts to be identified. A<br />
manual input mode is also available.<br />
Applications<br />
A true vertical depth survey log for correcting depth<br />
measurements<br />
Identify multiple zones, gradients, <strong>and</strong> contacts<br />
Features<br />
Multiple gradient plots for each zone<br />
An unlimited number of gradient lines that can be<br />
generated from RTS analysis data<br />
Fluid contacts can be identified <strong>and</strong> annotated on plots<br />
Minimizes errors because data is automatically imported<br />
from the RTS analysis program<br />
Verifies the quality of pressure data by automatically<br />
producing the hydrostatic gradient<br />
+ +<br />
+<br />
0.10<br />
0.09<br />
0.08<br />
0.07<br />
0.06<br />
0.05<br />
0.04<br />
0.03<br />
0.02<br />
0.01<br />
0<br />
+ +++++++++++++++++++++++++++++<br />
+++<br />
+++<br />
+<br />
++<br />
++++++<br />
+ +<br />
+ + ++++++<br />
+<br />
+<br />
7<br />
6<br />
5<br />
4<br />
3<br />
2<br />
1<br />
0<br />
0 500 1000 1500 2000 2500 3000 3500 4000<br />
Pressure (QPRS, psi)<br />
2-42 Reservoir Evaluation <strong>Services</strong><br />
Pretest Volume Fraction (^Volume/Total Volume)<br />
PVT plots the volume fraction against the pressure. The linear<br />
portion of the plot determines the compressibility <strong>and</strong> when the<br />
curve deviates from this linear trend, the bubblepoint is detected.<br />
Tvd (ft)<br />
3200<br />
3300<br />
3400<br />
3500<br />
3600<br />
HAL9249<br />
PRESSURE GRADIENT PLOT<br />
Legend<br />
Unassigned Pform<br />
Group 1: 0.377<br />
Group 2: 0.261<br />
Group 3: 0.275<br />
Group 4: 0.957<br />
Group 5: 0.268<br />
3,613.351 ft<br />
3700<br />
400 600 800 1000 1200 1400 1600 1800<br />
Pressure (psi)<br />
Pressure gradient plots allow multiple zones, gradients, <strong>and</strong> contacts to<br />
be identified. Plots are derived from RTS analysis data <strong>and</strong> are<br />
automatically added to the gradient analysis when data selections are<br />
made from real-time data. A manual input mode is also available.<br />
Pretest Volume Change (cc)
Test<br />
No.<br />
Test Identification<br />
MD<br />
(m)<br />
TVD<br />
(m)<br />
Hydrostatic<br />
Pressure<br />
Phyds1<br />
(psi)<br />
Phyds2<br />
(psi)<br />
Example of Pressure Test Summary<br />
Equivalent Mud<br />
Weight<br />
EqFmM<br />
w<br />
#/Gal<br />
EqBhMw<br />
#/Gal<br />
Test Pressures Test Times<br />
1.1 2892.90 2755.23 4219.07 4217.79 6.5 8.98 4301.96 3002.60 3053.43 286 342 395<br />
1.2 2892.90 2755.23 4219.07 4217.79 6.5 8.98 3050.07 2996.47 3053.41 470 487 627<br />
2.1 2899.98 2761.96 4220.33 4224.27 6.49 8.96 4328.67 2985.81 3058.43 353 381 492<br />
2.2 2899.98 2761.96 4220.33 4224.27 6.49 8.96 3058.30 3036.94 3058.19 505 564 574<br />
Reservoir Evaluation <strong>Services</strong> 2-43<br />
Pdd<br />
(psi)<br />
Tfu<br />
(sec)<br />
Tstop<br />
(sec)<br />
Tdd<br />
(sec)<br />
Pfu<br />
(psi)<br />
Pstop<br />
(psi)<br />
Remarks<br />
10 cc<br />
Effective<br />
Pre Test<br />
10 cc<br />
Effective<br />
Pre Test<br />
Good<br />
Test<br />
10 cc<br />
Effective<br />
Pre Test<br />
3.1 2909.48 2770.97 4234.52 4232.36 6.48 8.96 3074.09 1682.64 3064.64 437 512 1119 Tight Test<br />
4.1 2984.55 2842.19 4312.47 4313.45 6.69 8.89 4396.87 3141.33 3242.76 308 381 506<br />
Good<br />
Test<br />
4.2 2984.55 2842.19 4312.47 4313.45 6.69 8.89 3242.76 3134.49 3242.66 506 580 708<br />
Good<br />
Test<br />
Legend:<br />
Phyds1 Initial Hydrostatic Pressure<br />
Phyds1 Final Hydrostatic Pressure<br />
Pdd Initial Drawdown Pressure<br />
Pfu Final Drawdown or Fillup Pressure<br />
Pstop Final Buildup Pressure<br />
EqFmMw Equiv. Formation Mud Weight (PStop / (TVD*Constant))<br />
EqBhMw Equivalent Borehole Mud Weight (Phyds1 / (TVD*Constant))<br />
Tdd Initial Drawdown Time<br />
Tfu Final Drawdown or Fillup Time<br />
Tstop Final Buildup Time<br />
The Pressure Test Summary table compiles all pressure selections from the RTS program. Pressure tests are documented<br />
in a single table that is plotted on the log. This data is also available in ASCII form that can be easily imported into a spreadsheet for analysis.<br />
Test<br />
No.<br />
Example of Pressure Transient Analysis Summary<br />
Test Identification PTA Pressure PTA Mobilities Dual Probe Anistropy<br />
MD<br />
(m)<br />
TVD<br />
(m)<br />
Psphere<br />
(psi)<br />
Pfast<br />
(psi)<br />
Ptight<br />
(psi)<br />
Msphere<br />
(md/cp)<br />
Mfast<br />
(md/cp)<br />
Mtight<br />
(md/cp)<br />
Msdd<br />
(md/cp)<br />
Mh<br />
(md/cp)<br />
ANISO<br />
(Kv/Kh)<br />
Remarks<br />
1.1 2892.90 2755.23 3053.73 0.00 3052.98 2.10 0.00 5.30 11.69 Good Perm<br />
1.2 2892.90 2755.23 3053.57 3053.59 0.00 3.52 3.96 3.96 34.81 Good Perm<br />
2.1 2899.98 2761.96 3058.57 0.00 0.00 1.75 0.00 0.00 16.46 Good Perm<br />
2.2 2899.98 2761.96 3063.21 0.00 0.00 1.79 0.00 0.00 26.41 Good Perm<br />
3.1 2909.48 2770.97 0.00 0.00 3057.06 0.00 0.00 0.04 0.32 Low Perm<br />
4.1 2984.55 2842.19 3243.07 0.00 0.00 1.27 0.00 0.00 4.48<br />
Test performed<br />
at engineers<br />
request, Good<br />
Perm<br />
4.2 2984.55 2842.19 3242.78 0.00 0.00 1.53 0.00 0.00 4.17 Good Perm<br />
Legend:<br />
Psphere* Spherical Analysis Formation Pressure<br />
Pfast* FasTest Analysis Formation Pressure<br />
Ptight Tight Zone Analysis Formation Pressure<br />
Msphere Spherical Mobility<br />
Mfast FasTest Mobility<br />
Mtight Tight Zone Mobility<br />
Msdd Spherical Drawdown Mobility Mh Horizontal Mobility ANISO Anisotropy (Kv/Kh)<br />
The Pressure Transient Analysis Summary table is a tabular listing of pressure buildup analysis data, including mobility estimates <strong>and</strong> formation pressure<br />
projections (P*). Data is also available in real time <strong>and</strong> as a document on the log.
Well Testing<br />
Well testing is performed to determine formation<br />
productivity/deliverability, permeability, reservoir pressure,<br />
presence of skin damage, flow profile inside a formation <strong>and</strong><br />
wellbore, reservoir geometry/size/drainage area, inter-well<br />
communication, <strong>and</strong> perforation efficiency.<br />
Well testing is usually performed right after a well is<br />
completed <strong>and</strong> when the productivity does not follow the<br />
expected trends. Well testing is also done periodically<br />
through the life of a well <strong>and</strong> field to assess well performance<br />
<strong>and</strong> to establish pressure <strong>and</strong> rate decline patterns.<br />
In pressure transient testing, the changes in pressure,<br />
temperature, <strong>and</strong> fluid properties caused by sudden changes<br />
in production rates of oil, gas, <strong>and</strong> water from a well (or<br />
wells) are measured <strong>and</strong> analyzed during a given time span.<br />
The most widespread type of pressure transient testing is a<br />
pressure buildup test in which a producing well is shut-in,<br />
<strong>and</strong> the pressure values are recorded with time. In a pressure<br />
drawdown test, a shut-in well is opened, <strong>and</strong> the pressure<br />
values are recorded with time.<br />
The basic requirements of a well test are:<br />
Measuring the flow rate of the gas <strong>and</strong> the liquids<br />
produced or injected<br />
Controlling <strong>and</strong> adjusting the flow from the reservoir<br />
Measuring the pressures <strong>and</strong> temperatures using<br />
sensitive <strong>and</strong> accurate downhole instruments<br />
Obtaining samples of the reservoir fluids<br />
Safely disposing of or storing the well effluent produced<br />
during the test<br />
Well Test Design<br />
In a well test design, all the production history <strong>and</strong> the<br />
available reservoir <strong>and</strong> wellbore properties of a well are<br />
included in a pressure transient testing design model. A given<br />
reservoir flow geometry based on the completion <strong>and</strong><br />
production history is selected to simulate pressure <strong>and</strong> time<br />
data as close as the actual data which would be obtained from<br />
an ensuing well testing. For the unknown parameters,<br />
sensitivity runs should be conducted to cover the entire range<br />
of the expected values. Test duration <strong>and</strong> types should then<br />
be modified to provide a sufficient amount of data to be<br />
recommended for the ensuing pressure transient testing.<br />
Types of well tests include closed chamber or surge test with<br />
the zero-emission FasTest® system, shoot <strong>and</strong> pull test,<br />
drillstem test, cleanup test, slug test, early production test,<br />
multi-rate production/ injection well tests, reservoir limit<br />
test, permanent gauge test, <strong>and</strong> interference/pulse tests.<br />
For these tests to be reliable <strong>and</strong> effective, a well test design is<br />
critical to assuring the test objectives are feasible by selecting:<br />
Proper completion equipment<br />
Pressure gauges with the required sensitivity <strong>and</strong><br />
accuracy<br />
Type of well test<br />
Flow rate <strong>and</strong> choke sizes<br />
Duration of flow <strong>and</strong> shut-in periods<br />
The following well <strong>and</strong> reservoir models are considered when<br />
designing or analyzing well test data:<br />
Analytic <strong>and</strong> numeric models<br />
Homogeneous or dual porosity formations<br />
Horizontal, vertical, or deviated wellbores<br />
Hydraulic fracture wellbores<br />
Any boundary configuration<br />
Radial <strong>and</strong> linear composite reservoirs<br />
Layered reservoirs<br />
Wellbore with limited entry (partial completions)<br />
Changing wellbore storage <strong>and</strong>/or skin<br />
Turbulent flow <strong>and</strong> tidal effects<br />
Well interference effects<br />
Simultaneous analysis of a changing reservoir model<br />
before <strong>and</strong> after a stimulation or a workover application<br />
Material balance effects<br />
The accuracy <strong>and</strong> the value obtained from a well test design<br />
depends on the following:<br />
Experienced engineers performing the service<br />
Availability of advanced well/reservoir models<br />
Comprehensive well test design report<br />
Comparisons with prior tests to establish trend<br />
Parameter sensitivity evaluation to signify the<br />
importance of the values obtained<br />
2-44 Reservoir Evaluation <strong>Services</strong>
Features<br />
The following features are included in a well test design<br />
report:<br />
–Optimum test times<br />
–Optimum flow rates<br />
– The right equipment suited for the job<br />
– Models with sensitivities to reservoir, fluid, <strong>and</strong><br />
wellbore parameters<br />
– Well test procedure<br />
Inputs<br />
A well test design is a planned activity that uses the prewell<br />
test well <strong>and</strong> reservoir information to optimize the<br />
test type, procedure, <strong>and</strong> time<br />
Success of a well test is greatly enhanced by coupling the<br />
well testing with the real- time operations (RTO)<br />
Wellbore data, reservoir data, fluid properties, stimulation treatment, information geology, seismic <strong>and</strong> environmental<br />
controls, surface facilities, previous production/injection problems<br />
Outputs Well test design report<br />
Reservoir Evaluation <strong>Services</strong> 2-45
Well Test Analysis<br />
A well test analysis report provides information about well<br />
productivity/deliverability, formation permeability, reservoir<br />
pressure, amount <strong>and</strong> type of damage, perforation efficiency,<br />
<strong>and</strong> flow type /profile inside a formation <strong>and</strong> wellbore. If the<br />
test was designed <strong>and</strong> conducted for a longer period, then<br />
reservoir geometry/size/drainage area <strong>and</strong> inter-well<br />
communication would also be evaluated <strong>and</strong> provided in the<br />
report. Well test <strong>and</strong> completion data can be deployed to get<br />
a more accurate reservoir description.<br />
In a well test report, <strong>Halliburton</strong> engineers identify<br />
opportunities to improve well performance, which often<br />
includes reservoir <strong>and</strong> well production projection with<br />
recommendations to enhance productivity. If a well test<br />
identifies wellbore damage, then productivity improvement<br />
projections will be simulated to compare acidizing with<br />
hydraulic fracturing <strong>and</strong> frac pack to evaluate if stimulation<br />
will improve production. If the cause of the problem stems<br />
from partial completion <strong>and</strong> perforation plugging, then reperforation,<br />
acidizing, <strong>and</strong> fracturing cases will be compared.<br />
The optimum production scenario based on the evaluated<br />
reservoir <strong>and</strong> wellbore parameters can also be included in the<br />
report.<br />
Well test analysis can provide initial reservoir pressure (p i),<br />
permeability thickness (k h), <strong>and</strong> skin (S). Additionally, the<br />
perforated wellbore length (h w), distance of horizontal<br />
wellbore to bottom of formation (Z w), <strong>and</strong> ratio of vertical to<br />
radial permeability (k Z/k r) are calculated for horizontal<br />
wells. The dual-porosity flow model provides values for λ<br />
<strong>and</strong> ω. Stimulated wells are characterized by the fracture<br />
half-length (X f), conductivity (C FD), <strong>and</strong> fracture skin.<br />
Distances to boundaries <strong>and</strong> the boundary type (no-flow,<br />
constant pressure, or leaky) can be provided for any of the<br />
models. In a composite reservoir, the size <strong>and</strong> the properties<br />
inside <strong>and</strong> outside of the composite zone will be provided. In<br />
a limited entry well, the effective interval producing into the<br />
wellbore <strong>and</strong> the plugged perforations are identified. In<br />
layered reservoirs, permeability, skin, pressure, <strong>and</strong> flow rate<br />
for each layer can be calculated.<br />
A well test analysis technique may include one or a<br />
combination of the following methods:<br />
Conventional linear regression analysis<br />
Type curve analysis<br />
Non-linear regression<br />
Closed-chamber DST analysis<br />
Production analysis<br />
<strong>Halliburton</strong> well test analysis service differentiating factors<br />
include:<br />
Experienced reservoir engineers performing the service<br />
Customized <strong>and</strong> easy to use report<br />
Advanced well/reservoir models<br />
Analytic <strong>and</strong>/or numeric analysis techniques<br />
Real-time analysis capabilities using a secured website<br />
that can be accessed using your computer anytime or<br />
anywhere<br />
Features<br />
Enhanced reservoir <strong>and</strong> completion description with<br />
advanced <strong>and</strong> sophisticated reservoir models<br />
Evaluation <strong>and</strong>/or analysis performed in batch or real<br />
time<br />
Recommendations for well improvement based on<br />
reservoir, wellbore, completion, <strong>and</strong> the surface<br />
equipment<br />
Fast turnaround at a reasonable cost to free up valuable<br />
engineering time<br />
Experienced reservoir engineers available for any<br />
questions<br />
Evaluation of the entire job<br />
Follow-up briefing on analyses results <strong>and</strong><br />
recommendations for future tests<br />
A complete analysis report with:<br />
– Well test description<br />
– System evaluation<br />
– Discussion of each event<br />
– Gauge comparison<br />
– Analysis results<br />
– Well test data summary<br />
– Historical comparisons (when applicable)<br />
– Production improvement recommendations<br />
(when applicable)<br />
– Conclusions<br />
2-46 Reservoir Evaluation <strong>Services</strong>
Multi-Layered Analysis<br />
In multi-layered reservoirs, hydrocarbon fluids exist in<br />
different layers. These layers could be located close or far<br />
from each other, in hydraulic communication or totally<br />
isolated from each other, <strong>and</strong> with similar or completely<br />
different properties. The pressure values in the layers could<br />
differ by just the hydrostatic head pressure difference or be<br />
totally different from each other. Multi-layer formations are<br />
divided into two main categories of:<br />
Commingled layered reservoirs – The layers in a<br />
commingled formation are isolated from each other <strong>and</strong><br />
do not communicate in the reservoir. They are<br />
hydraulically connected with each other through the<br />
wellbore<br />
Cross-flow layered reservoirs – The layers in a cross-flow<br />
reservoir communicate with each other through both the<br />
formation <strong>and</strong> the wellbore. At any point in the reservoir,<br />
the interlayer cross flow is proportional to the pressure<br />
difference between the layers<br />
At high flow rates, the high permeability layers produce at<br />
higher flow rates than the low permeability layers, <strong>and</strong> thus,<br />
they get depleted at a faster rate. At low flow rates or when<br />
the well is shut-in at surface, fluids from the low permeability<br />
layers invade the high permeability layers which were<br />
depleted more.<br />
<strong>Halliburton</strong> provides a multi-rate, multi-layer test in<br />
conjunction with the production logging service. Layer<br />
pressure <strong>and</strong> flow rates are evaluated by the production<br />
logging service. This information is fed into the multi-layer<br />
well test analysis program to evaluate permeability, skin, <strong>and</strong><br />
pressure for each layer.<br />
5500Analysis Results<br />
Gas Rate<br />
[Mscf/D] BHP [psia]<br />
4500<br />
3500<br />
4000<br />
Skin vs. Rate<br />
0 20 40 60 80 100 120 140<br />
History plot (Pressure [psia], Gas Rate [Mscf/D] vs Time [hr])<br />
Multi-rate test showing analysis results accounting for<br />
turbulent flow effects.<br />
Inputs<br />
14<br />
12<br />
10<br />
8<br />
6<br />
4<br />
2<br />
Skin<br />
-1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000<br />
Rate [Mscf/D]<br />
Prod Index = 4.95 Mscf/D - psi<br />
Storage Constant = 0.00509 STB/psi<br />
True Skin = 1.96<br />
True Delta P Skin = 71 psi<br />
Turb Skin = 4.58<br />
Turb Delta P Skin = 165 psi<br />
Turb Factor = 0.00131 1/Mscf/D<br />
Initial Pressure = 6000 psia<br />
kh = 141 md-ft<br />
k = 4.7 md<br />
HAL7687<br />
Permanent Gauge Analysis: History plot of pressure <strong>and</strong> rate showing<br />
analysis model match<br />
Reservoir shape: Analysis results showing geologic boundary configuration<br />
Inflow <strong>and</strong> outflow pressure—rate responses for various reservoir<br />
parameters showing production match point.<br />
Reservoir Evaluation <strong>Services</strong> 2-47<br />
BHP [psia]<br />
Gas Rate<br />
[Mscf/D]<br />
HAL7755<br />
FLOWING BTM PRES psig<br />
9000<br />
8000<br />
7000<br />
6000<br />
5000<br />
4000<br />
3000<br />
5000<br />
4900<br />
4800<br />
4700<br />
9000<br />
HAL7688<br />
FORM PERM<br />
(md )<br />
50<br />
50<br />
100<br />
100<br />
250<br />
250<br />
Constraints:<br />
Erosion:C=100.00<br />
2000<br />
0 2000<br />
Pressure vs Time<br />
Gas Rate vs Time<br />
0 1000 2000 3000 4000 5000 6000<br />
Inflow Parameter<br />
Pressure [psia], Gas Rate [Mscf/D] vs Time [hr])<br />
3,000 ft<br />
Production Data Matching Theoretical Model<br />
SKIN<br />
( )<br />
0<br />
5<br />
0<br />
5<br />
0<br />
5<br />
Match<br />
Point<br />
Pbar<br />
3,000 ft<br />
2,500 ft<br />
2,000 ft<br />
Outflow Parameter<br />
FLNCHOK ID<br />
(1/64 )<br />
12<br />
16<br />
20<br />
26<br />
36<br />
64<br />
HAL7689<br />
4000 6000 8000 10000<br />
FLOW RATE bbl/d<br />
Test objectives, geologic information, prior production data, completion schematic, fluid property data, prior treatment<br />
data, well test downhole pressure gauge files, well test surface data report files<br />
Outputs Well test analysis report including recommendations for well performance improvement (when needed)
Reservoir Evaluation<br />
SigmaSat Model<br />
This cased-hole interpretation model is designed for<br />
saturation analysis of a single well based on sigma logs from<br />
any supplier. Oil saturation can be determined in the<br />
presence of saline formation waters. Gas saturation can be<br />
determined under almost any conditions.<br />
Features<br />
Saturation interpretation of any formation sigma data<br />
St<strong>and</strong>ard volumetric analysis or an adaptation of the<br />
Chevron variable matrix model<br />
Inclusion of open-hole porosity <strong>and</strong> clay volume<br />
analyses<br />
St<strong>and</strong>-alone analysis using porosity <strong>and</strong> clay indicators<br />
from cased-hole monitoring tools or any available source<br />
Determines volume of hydrocarbons produced from the<br />
reservoir <strong>and</strong> allows estimates of remaining reserves<br />
Enhances reservoir production knowledge<br />
Allows better underst<strong>and</strong>ing of hydrocarbon drainage<br />
efficiency from the reservoir<br />
Identifies potential hydrocarbon production zones that<br />
have not been drained or were bypassed or previously<br />
undiscovered<br />
Pinpoints changing oil/water <strong>and</strong> gas/oil contacts<br />
through time lapse monitoring<br />
Finds flooded or swept zones<br />
Associated Answer <strong>Products</strong> <strong>and</strong> Pre-Processing<br />
Software<br />
Pulse-height spectral gain stabilization <strong>and</strong> processing,<br />
plus environmental corrections (TMDLRL)<br />
CarbOxSat model – similar model for saturation<br />
analysis of neutron decay logs<br />
TripleSat model – similar family of models utilizing<br />
both carbon/oxygen <strong>and</strong> neutron decay logs for use<br />
where three fluids are present in the reservoir<br />
Inputs Clay volume, total porosity, effective porosity, environmentally corrected intrinsic sigma<br />
Outputs<br />
Track 1 indicates the amount of s<strong>and</strong> <strong>and</strong> shale by volume, along with<br />
the effective porosity. Track 2 is a porosity overlay track indicating<br />
hydrocarbon crossover. Track 3 shows sigma water apparent <strong>and</strong> sigma<br />
solids apparent. Track 4 shows an envelope of sigma wet <strong>and</strong> sigma<br />
hydrocarbon with sigma intrinsic in between, indicating the<br />
hydrocarbon. Track 5 indicates the total hydrocarbon saturation, <strong>and</strong><br />
Track 6 shows total porosity, effective porosity, the effective volume of<br />
water, <strong>and</strong> the volume of hydrocarbon.<br />
2-48 Reservoir Evaluation <strong>Services</strong><br />
HAL11409<br />
Individual <strong>and</strong> combined clay volume, total porosity, effective porosity, capture-ratio porosity, inelastic ratio porosity,<br />
hydrocarbon volume, total <strong>and</strong> effective hydrocarbon saturation, water volume
CarbOxSat Model<br />
This interpretive model is specifically designed for saturation<br />
analysis of a single well based on <strong>Halliburton</strong> carbon/oxygen<br />
(C/O) logs. The CarbOxSat model is used for interpreting<br />
oil saturation in reservoirs where formation water salinity is<br />
fresh, mixed, or unknown.<br />
Features<br />
Saturation interpretation of all <strong>Halliburton</strong> formation<br />
carbon/oxygen data<br />
<strong>Halliburton</strong>’s lithology compensated Delta-C/O or<br />
traditional overlay method<br />
Inclusion of open-hole porosity <strong>and</strong> clay volume<br />
analyses<br />
St<strong>and</strong>-alone analysis using porosity <strong>and</strong> clay indicators<br />
from cased-hole monitoring tools or any available source<br />
Determines volume of hydrocarbons produced from the<br />
reservoir <strong>and</strong> allows estimates of remaining reserves<br />
Enhances reservoir production knowledge<br />
Allows better underst<strong>and</strong>ing of hydrocarbon drainage<br />
efficiency from the reservoir<br />
Identifies potential hydrocarbon production zones that<br />
have not been drained or were bypassed or previously<br />
undiscovered<br />
Pinpoints changing oil/water <strong>and</strong> gas/oil contacts<br />
through time lapse monitoring<br />
Finds flooded or swept zones<br />
Associated Answer <strong>Products</strong> <strong>and</strong> Pre-Processing<br />
Software<br />
Pulse-height spectral gain stabilization <strong>and</strong> processing<br />
(RMTERL)<br />
Multi-pass stacking (RMTEAVG)<br />
Environmental corrections (RMTECOR)<br />
SigmaSat model – similar model for saturation analysis<br />
of neutron decay logs<br />
TripleSat model – similar family of models utilizing<br />
both carbon/oxygen <strong>and</strong> neutron decay logs for use<br />
where three fluids are present in the reservoir<br />
Track 1 contains the open-hole neutron <strong>and</strong> density porosity curves, as<br />
well as the gamma ray curve. Track 2 contains the cased-hole porosity<br />
indicators of a pseudo-density curve from the inelastic ratio, <strong>and</strong> a<br />
pseudo-neutron porosity from the capture ratio. Track 3 contains the<br />
delta-C/O envelope indicating the C/O interpretation. Track 5 shows the<br />
total hydrocarbon saturation, <strong>and</strong> Track 6 is a volumetrics track<br />
containing the volume of shale, effective porosity, <strong>and</strong> the bulk volume<br />
of water to provide water <strong>and</strong> hydrocarbon saturation.<br />
Inputs Clay volume, total porosity, effective porosity, environmentally corrected carbon/oxygen <strong>and</strong> calcium/silica ratios<br />
Outputs<br />
Individual <strong>and</strong> combined clay volume, total porosity, effective porosity, capture-ratio porosity, inelastic ratio porosity,<br />
volume of oil, total <strong>and</strong> effective oil saturations, water volumes<br />
Reservoir Evaluation <strong>Services</strong> 2-49<br />
HAL11768
TripleSat Model<br />
This unique interpretation model is specifically designed for<br />
use with <strong>Halliburton</strong>’s reservoir monitoring tools. The<br />
TripleSat model employs a combination of C/O <strong>and</strong> sigma<br />
measurements <strong>and</strong> is used to calculate saturation when three<br />
fluids are present in the reservoir.<br />
Features<br />
Utilizes simultaneously-recorded sigma <strong>and</strong> C/O<br />
measurements<br />
Provides more accurate interpretation in oil producing<br />
reserves where steam or gas is present<br />
Contains selectable sets of equations that can be<br />
optimized for one of the following:<br />
–Steamflood<br />
– Oil drainage from gas cap<br />
– Gasflood<br />
–Sea waterflood<br />
Allows additional optimizations to be readily<br />
constructed, some using a <strong>Halliburton</strong> adaptation of the<br />
Chevron gas correction to carbon/oxygen logs<br />
Permits inclusion of open-hole porosity <strong>and</strong> clay volume<br />
analyses<br />
Allows st<strong>and</strong>-alone analysis using porosity <strong>and</strong> clay<br />
indicators from cased-hole monitoring tools or any<br />
available source<br />
Allows accurate interpretation in reservoirs that have gas<br />
cap development or are under steamflood or gasflood<br />
Permits interpretation in reservoirs with retrograde<br />
condensate production<br />
Associated Answer <strong>Products</strong> <strong>and</strong> Pre-Processing<br />
Software<br />
SigmaSat model – neutron decay time saturation<br />
analysis<br />
CarbOxSat model – carbon/oxygen saturation analysis<br />
Inputs<br />
Outputs<br />
KernSat Interpretation Example. This well located in Kern County,<br />
California in the Kern River Field, is in an active steamflood<br />
hydrocarbon recovery project. This log is an example of our customized<br />
interpretation model KernSat. Track 4 of the example displays the<br />
computed oil saturation (shaded in green) <strong>and</strong> the gas saturation<br />
(shaded in red). These saturations were computed using a combination<br />
of carbon-oxygen ratio <strong>and</strong> formation sigma. Track 3 displays the<br />
carbon-oxygen <strong>and</strong> the calcium-silicon ratio curves. The green shading<br />
between the two curves indicates hydrocarbons in the formation. Also<br />
displayed in the track are the natural gamma ray measurement <strong>and</strong> the<br />
simultaneous recorded formation sigma. Tracks 1 <strong>and</strong> 2 display a<br />
comparison of the open-hole density <strong>and</strong> neutron porosities <strong>and</strong> the<br />
porosity ratio indicators measured by the RMT Elite analysis. Track 1<br />
is the open-hole density neutron porosity. Steam measured in the<br />
formation at the time of the log is indicated by the gray shading between<br />
the curves. Tracks 2 displays the inelastic <strong>and</strong> capture ratios measured<br />
from the RMT Elite analysis. The red shading indicates the current<br />
location of steam in the reservoir. This example indicates that the steam<br />
chest has exp<strong>and</strong>ed when compared to the original formation contacts.<br />
The depth track recorded at the far left side of the log displays water flow<br />
measured by the RMT Elite analysis outside the casing.<br />
Clay volume, total porosity, effective porosity, environmentally corrected carbon-oxygen <strong>and</strong> calcium-silica ratios,<br />
environmentally corrected sigma<br />
Individual <strong>and</strong> combined clay volume, total porosity, effective porosity, capture-ratio porosity, inelastic ratio porosity,<br />
volume of oil, total <strong>and</strong> effective oil saturations, water volumes, corrected three-phase saturations<br />
2-50 Reservoir Evaluation <strong>Services</strong><br />
HAL9180
Production Logging Analysis<br />
Production Logging Analysis<br />
<strong>Halliburton</strong> has several programs that are used to interpret<br />
production logs. The basic production logging interpretation<br />
is provided using Kappa Engineering's Emeraude software.<br />
The industry st<strong>and</strong>ard in production logging is Emeraude<br />
which allows for a common platform for communication<br />
<strong>and</strong> evaluation between service companies <strong>and</strong> operators.<br />
From vertical injectors to horizontal or highly deviated<br />
multiphase producers, Emeraude provides a comprehensive<br />
<strong>and</strong> intuitive set of tools to produce results from the log data<br />
from simple through to the most sophisticated toolstrings.<br />
The basic interpretation uses raw PL data from the spinner,<br />
fluid density, pressure, <strong>and</strong> temperature tools to determine<br />
flow rates of the well. The log at the right consists of seven<br />
passes logged at different multiple logging speeds as shown<br />
by the different colors for each pass. The basic interpretation<br />
process is explained as follows:<br />
Spinner calibration <strong>and</strong> apparent velocity<br />
The user defines the spinner calibration zones to<br />
determine the spinner calibration with or without<br />
thresholds values. After each calibration, an apparent<br />
velocity curve is generated<br />
Single <strong>and</strong> zoned PVT<br />
The next step is to use the PVT model to provide the<br />
properties of any phase at any temperature <strong>and</strong> pressure.<br />
Several different correlations may be used for each <strong>and</strong><br />
every inflow zone<br />
Flow rates<br />
Using a nonlinear regression method, the rate<br />
calculations for each inflow zone is determined. This<br />
allows the user full flexibility in the number <strong>and</strong> type of<br />
input measurements. The basic calculation scheme<br />
successively solves the cumulative rates at selected depths<br />
inside the wellbore. The contributions of the user<br />
selected inflow zones are then obtained from successive<br />
differences above <strong>and</strong> below each zone. To further<br />
enhance the product, a global regression allows<br />
comparisons between zones<br />
Interpretation models<br />
Emeraude offers a full range of flow models from single<br />
to three-phase flow. Specific models are provided to<br />
h<strong>and</strong>le flow re-circulation as well as flow through<br />
st<strong>and</strong>ing water columns. Emeraude can be tightly<br />
controlled by the user to provide a solution to complex<br />
flow situations including fallback, three-phase, <strong>and</strong><br />
deviated wellbores<br />
Basic raw data showing two sets of perforations (red), two sets of spinner<br />
calibration zones (yellow), <strong>and</strong> three rate calculation zones (grey). From<br />
the fluid density data, it is possible to see where there are major fluid<br />
composition changes (4480), with minor changes from 4480 to 4550. The<br />
spinner information also indicates fluid entry around 4480.<br />
Reservoir Evaluation <strong>Services</strong> 2-51
This screen capture shows the spinner calibration in the sump. The positive <strong>and</strong> negative thresholds are applied to<br />
the other zones to correct for spinner friction.<br />
This zone is above the top set of perforations, so the velocity at this zone should be the velocity of the total fluid<br />
flow. The calculated velocity will be corrected for tool position in later sections of the software.<br />
2-52 Reservoir Evaluation <strong>Services</strong>
Several programs were developed in-house for specialized<br />
tools but are linked to Kappa Engineering's Emeraude<br />
program. These specialized analysis programs are used to<br />
process specific logging tool data to determine fluid velocities<br />
<strong>and</strong> holdups.<br />
GHTA gas holdup tool analysis<br />
FloImager® analysis service for CAT capacitance array<br />
tool data<br />
SatImager analysis for spinner array tool (SAT) data<br />
The GHTA model is an analysis program used to process the<br />
data from the GHT gas holdup tool <strong>and</strong> create a gas holdup<br />
for further processing in Emeraude.<br />
The FloImager model uses data from the CAT tool to provide<br />
an accurate holdup calculation. Like the GHTA model, the<br />
output from the FloImager model is used seamlessly in the<br />
Emeraude software to further quantify the production rates.<br />
The SatImager model uses data from the SAT tool to provide<br />
an accurate image of the velocity profile in the wellbore. The<br />
SAT tool with six spinners allows interpretation of complex<br />
flow regimes including downflow <strong>and</strong> liquid fallback.<br />
Combining the FloImager <strong>and</strong> SatImager models in<br />
Emeraude provides an efficient method to evaluate<br />
complicated downhole flow regimes including deviated,<br />
horizontal, <strong>and</strong> three-phase.<br />
Features<br />
Delivers a complete interpretation of production logs<br />
Detailed analysis of downhole <strong>and</strong> surface production<br />
rates, both continuous <strong>and</strong> averaged, over the desired<br />
interval<br />
H<strong>and</strong>les a multiple array of production logging sensors<br />
including the new generation fullbore holdup tools<br />
Allows customized analysis using customer PVT inputs<br />
<strong>and</strong> slip velocities<br />
Various presentations <strong>and</strong> stringent quality control<br />
promotes more accurate PL analysis of production <strong>and</strong><br />
injection wells including the difficult three-phase flow in<br />
horizontal wells<br />
Continuous logs provide more accurate determination<br />
of fluid entry points which allow for improved<br />
conformance treatments<br />
Averaged <strong>and</strong> zonal production rates provide valuable<br />
information in determination of treatments <strong>and</strong>/or<br />
remedial work<br />
Log presentations can be customized to meet the specific<br />
requests or needs<br />
Text files provide linkages to reservoir models <strong>and</strong> other<br />
analysis packages<br />
Final Emeraude product showing two-phase flow showing the lower<br />
perforations taking fluid. Track 1 provides information about the<br />
holdups, or the cross-sectional area of the pipe that the phase is<br />
occupying. Track 2 is the continuous flow rate measurement in STB/day.<br />
Track 3 is the zonal average of the two phases while Track 4 shows the<br />
production of each zone. In this case the lower zone is taking a large<br />
amount of water that is being produced by the upper zone.<br />
Reservoir Evaluation <strong>Services</strong> 2-53
FloImager ® Analysis Service<br />
The FloImager® analysis service is a logging service product<br />
that uses the data from the CAT capacitance array tool to<br />
provide accurate three-phase holdup calculations. This<br />
application is extremely useful in highly deviated <strong>and</strong><br />
horizontal wells having multiphase flow. Applications for<br />
detecting three-phase fluid entry can be done at any angle.<br />
There are a multitude of applications for the FloImager<br />
analysis service. In addition to measuring fluid holdup, the<br />
FloImager analysis service can be used to detect water entry<br />
<strong>and</strong> its orientation relative to high side of pipe at any well<br />
deviation. The FloImager analysis service can successfully<br />
show three-phase fluid segregation since each fluid has its<br />
own log response. The FloImager analysis service provides an<br />
accurate visualization of the undulating horizontal wellbore<br />
when TVD data is combined with CAT tool data. Combining<br />
the calculated fluid holdup with additional PL sensors allow<br />
a more accurate <strong>and</strong> complete three-phase analysis.<br />
The FloImager analysis service improves interpretation of the<br />
flow patterns in all wells due to the increased number of<br />
sensors at the same depth. More accurate holdups can be<br />
determined because the relative position of the CAT tool is<br />
monitored, correcting the images <strong>and</strong> logs to the high side of<br />
the hole.<br />
FloImager 3D Software Analysis<br />
The FloImager 3D software provides a 3D method of viewing<br />
data from the FloImager service. The FloImager 3D software<br />
allows the customer to view, rotate, <strong>and</strong> manipulate CAT<br />
capacitance array tool data to underst<strong>and</strong> the flow patterns<br />
<strong>and</strong> character of the well. Both the FloImager 3D <strong>and</strong><br />
FloImager service use data from the CAT tool to provide<br />
accurate three-phase holdup calculations.<br />
FloImager 3D software allows a complete picture or profile of<br />
the downhole holdup pattern. This allows the viewer to<br />
approach the wellbore from any direction to allow multidimensional<br />
underst<strong>and</strong>ing of the flow characteristics. Since<br />
the sensors are normalized in the CAT tool, the same color<br />
pallet can be used for each sensor providing a precise image.<br />
The FloImager 3D software provides a superior technique for<br />
displaying multiphase holdup. However, since this<br />
segregation is dependent upon total fluid flow, each sensor<br />
has the ability to measure phase holdups of gas, oil, <strong>and</strong><br />
water. Both the FloImager 3D <strong>and</strong> the FloImager service have<br />
several options to calculate total holdup of the wellbore,<br />
allowing the user to determine the best possible solution to<br />
this complicated issue.<br />
Track 1 consists of a gamma ray (GR), relative bearing (RB),<br />
temperature (TEMP), pressure (PRES), <strong>and</strong> continuous spinner<br />
(FCON). RB is the relative bearing for arm 1 of the CAT tool <strong>and</strong><br />
allows arm position relative to the high side of the hole to be<br />
determined. Track 2 provides the image of the flow as measured by the<br />
CAT tool. The image is positioned so that the high sides are on the left<br />
<strong>and</strong> right side of the track while the middle is on the low side. Since this<br />
is a horizontal well, it should be apparent that the heavier fluids should<br />
be on the bottom <strong>and</strong> lighter fluids should be on the top of the well.<br />
Track 3 shows the average of the 12 sensors (AVCAPN) along with two<br />
center sample holdup measurements fluid density (FDEN) <strong>and</strong> hydro<br />
tool (HYDR). Track 4 provides a cross-sectional view of the data in<br />
Track 2. The right side of the image is high side while the left is on the<br />
bottom. The holdups are also presented in the last track, water (YWE)<br />
<strong>and</strong> gas (YGE). This presentation allows quick method of determined<br />
fluid contacts <strong>and</strong> provides accurate calculation of fluid compositions.<br />
Lines A <strong>and</strong> B correspond to the Flo3D section.<br />
2-54 Reservoir Evaluation <strong>Services</strong><br />
XX50<br />
XY00<br />
XY50<br />
A<br />
B
Features<br />
Multi-directional images available<br />
Continuous display of the flowing fluids<br />
More accurate three-phase holdup calculations<br />
Images in all types of stratified <strong>and</strong> mixed flow<br />
Designed for more accurate responses in both deviated<br />
<strong>and</strong> horizontal wells<br />
Excellent wellbore coverage with array of 12 sensors<br />
allows superior data <strong>and</strong> improved flow characterization<br />
A<br />
High Side View<br />
Low Side View<br />
Continuous holdup curves, fluid distribution mapping,<br />
<strong>and</strong> a view of the fluid distribution in cross-section<br />
allows clear-cut underst<strong>and</strong>ing of the flow profiles <strong>and</strong><br />
characteristics<br />
Ability to obtain more reliable holdup measurements<br />
<strong>and</strong> high-resolution fluid entry detection, location, <strong>and</strong><br />
orientation in deviated <strong>and</strong> horizontal wells<br />
XX90 XY00<br />
This output is from FloImager® 3D software analysis <strong>and</strong> shows 10 ft of the log from above. It is possible to see the changes in the holdup due either<br />
to wellbore trajectories or possible fluid inflow.<br />
XY00<br />
XX92<br />
Gas Holdup = .223<br />
Oil Holdup = .516<br />
Water Holdup = .261<br />
XX90<br />
This presentation is a composite from FloImager® 3D software analysis. The first display is over the same zone as above looking downhole. The last<br />
two images are from the cross-section display that shows both the tool arm position <strong>and</strong> the calculated holdups for the three phases. The white dot is<br />
arm #1 which determines the relative bearing so that the data can be oriented to the high side of the wellbore.<br />
Reservoir Evaluation <strong>Services</strong> 2-55<br />
B<br />
XX96<br />
Gas Holdup = .221<br />
Oil Holdup = .651<br />
Water Holdup =.128
2-56 Reservoir Evaluation <strong>Services</strong>
Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
Resistivity<br />
ACRt Array Compensated Resistivity Tool<br />
System<br />
The ACRt array compensated resistivity tool system<br />
represents the latest thinking in conventional array induction<br />
technology. Every aspect of mechanical, electrical, software,<br />
<strong>and</strong> signal processing design has been optimized to yield<br />
array induction measurements with unparalleled accuracy,<br />
stability, <strong>and</strong> dynamic range.<br />
The ACRt system is an asymmetric design that consists of a<br />
single transmitter operating at three frequencies <strong>and</strong> six<br />
receiver antennas with spacings from 6 to 80 in. A simple <strong>and</strong><br />
robust skin effect method utilizes only the in-phase<br />
components of the received signals at all three frequencies.<br />
Each tool is individually characterized for thermal drift<br />
during manufacture. This characterization, in concert with<br />
sonde-mounted temperature sensors, provides the basis of a<br />
proprietary <strong>and</strong> highly accurate temperature compensation<br />
method. Real-time borehole corrections are usually derived<br />
from a caliper source <strong>and</strong> a sonde-mounted mud cell. When<br />
the caliper input is absent (e.g. downlogging), borehole<br />
corrections are derived from the short-spaced induction<br />
receiver data alone. The final step in the processing chain,<br />
2D software focusing, produces five radial curves with<br />
matched vertical resolution <strong>and</strong> with radial focal depths of<br />
10, 20, 30, 60, <strong>and</strong> 90 in. The ACRt sonde includes an<br />
integrated SP sensor.<br />
Applications<br />
Accurate measures of formation resistivity at varying<br />
depths of investigation for enhanced estimates of Rt , Rxo ,<br />
<strong>and</strong> Di<br />
Quantitative assessment of Sw , Sxo , <strong>and</strong> moveable water<br />
volumes<br />
Qualitative assessment of permeability <strong>and</strong> rock quality<br />
Array induction measurements are available in<br />
formations with resistivities from 0.2 to 2000 ohm-m<br />
<strong>and</strong> in water, air, or oil-filled boreholes<br />
Analysis of finely-bedded formations<br />
Real-time 10-20-30-60-90 in. radial curves from the ACRt system are<br />
displayed in track 2. Good sensitivity to shallow invasion is in evidence<br />
in the zones 10290 <strong>and</strong> 10385. RT, RXO, DI <strong>and</strong> the graphical invasion<br />
map are available in real time.<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-1<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong>
Features<br />
State of the art processing scheme features:<br />
– 2D software focusing produce five resolutionmatched<br />
radial curves with radial focal depths of<br />
10, 20, 30, 60 <strong>and</strong> 90 in.<br />
– Real-time inversion for Rt , Rxo , Di, <strong>and</strong> invasion<br />
“map”<br />
– Proprietary thermal correction scheme<br />
– Three frequency skin effect correction<br />
– Real-time borehole corrections with or without<br />
caliper inputs<br />
– Resolution-match filters of 1, 2 <strong>and</strong> 4 ft<br />
Length<br />
ft (m)<br />
19.5<br />
(5.9)<br />
Minimum Borehole<br />
Diameter<br />
in. (mm)<br />
4.75<br />
(121)<br />
Optimized receiver antenna spacings provide improved<br />
sensitivity to shallow <strong>and</strong> mid-range mud filtrate<br />
invasion depths along with excellent deep response for Rt Receiver coil spacings closely approximate computed<br />
radial curve depths, which results in fundamentally<br />
stable processing<br />
Short array length reduces dependency on “speed<br />
correction” when encountering moderate overpulls<br />
Environmental ratings of 350°F <strong>and</strong> 20,000 psi<br />
Logging speeds up to 6,000 ft/hr<br />
ACRt Array Compensated Resistivity Tool Specifications<br />
Maximum Borehole<br />
Diameter<br />
in. (mm)<br />
12.25<br />
(311)<br />
Operating Pressure<br />
Rating<br />
psi (bar)<br />
20,000<br />
(1400)<br />
Operating<br />
Temperature Rating<br />
°F (°C)<br />
Weight<br />
lb (kg)<br />
Maximum Logging<br />
Speed<br />
ft/hr (m/hr)<br />
3-2 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
350<br />
(177)<br />
308<br />
(140)<br />
6,000<br />
(1830)
HRAI High Resolution Array Induction Tool<br />
The HRAI high resolution array induction tool represents<br />
a significant engineering advance over the HRI high<br />
resolution induction tool. The HRAI tool leverages the<br />
proven features of the HRI tool “three-coil” receiver<br />
configuration while providing induction measurements with<br />
six radial focal depths. The sonde is a symmetrical design,<br />
with five upper <strong>and</strong> five lower receivers positioned around a<br />
center-mounted transmitter. Raw conductivity data is<br />
collected at two frequencies, 8 <strong>and</strong> 32 kHz, <strong>and</strong> the receiver<br />
antennas are spaced from 17 to 78 in.<br />
A new speed correction algorithm implemented in the<br />
logging software enhances the accuracy of HRAI tool coil<br />
array data even during large overpulls in sticky boreholes.<br />
Long transmitter-receiver spacing <strong>and</strong> optimized array<br />
processing help to significantly reduce the effects of<br />
washouts, rugosity, <strong>and</strong> tool eccentricity.<br />
Applications<br />
Accurate measures of formation resistivity at varying<br />
depths of investigation for enhanced estimates of Rt , Rxo ,<br />
<strong>and</strong> Di<br />
Quantitative assessment of Sw , Sxo , <strong>and</strong> moveable water<br />
volumes<br />
Qualitative assessment of permeability <strong>and</strong> rock quality<br />
Array induction measurements are available in<br />
formations with resistivities from 0.2 to 2,000 ohm-m<br />
<strong>and</strong> in water, air, or oil-filled boreholes<br />
Analysis of finely-bedded formations<br />
Features<br />
Real-time 2D software focusing achieves an optimum<br />
balance of vertical resolution, radial focusing, <strong>and</strong><br />
symmetry of response<br />
Resolution-matched radial curves are computed with<br />
radial focal depths of 10, 20, 30, 60, 90 <strong>and</strong> 120 in.<br />
Description<br />
LOGIQ<br />
DIT<br />
Logging Speed<br />
ft//hr (m)<br />
6,000<br />
(1830)<br />
6,000<br />
(1830)<br />
Each resistivity comes with a 1-ft, 2-ft, <strong>and</strong> 4-ft vertical<br />
resolution<br />
Real-time Rt , Rxo , <strong>and</strong> Di curves <strong>and</strong> an invasion “map”<br />
are available<br />
Real-time borehole corrections facilitated by a sondemounted<br />
mud resistivity sensor<br />
Advanced “speed correction” algorithm for correcting<br />
array data for over-pulls in sticky boreholes<br />
Vertical resolution-matched elemental measurements<br />
High logging speeds up to 6,000 ft/hour are possible<br />
Real-time answer products of HRAI tool: an invasion map in Track 4, R t<br />
<strong>and</strong> R xo in Track 3, <strong>and</strong> Track 2 shows the 2-ft resolution radial resistivity<br />
curves.<br />
HRAI High Resolution Array Induction Tool Specifications<br />
Length<br />
ft (m)<br />
25.43<br />
(7.75)<br />
35<br />
(10.67)<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-3<br />
HAL3960<br />
Minimum Borehole<br />
Diameter<br />
in. (cm)<br />
4.5<br />
(11.43)<br />
4.5<br />
(11.43)<br />
Operating Pressure<br />
psi (bar)<br />
20,000<br />
(1400)<br />
20,000<br />
(1400)<br />
Operating<br />
Temperature<br />
°F (°C)<br />
350<br />
(177)<br />
300<br />
(150)<br />
Weight<br />
lb (kg)<br />
400<br />
(181)<br />
586<br />
(266.5)
HRI High Resolution Induction Tool<br />
The HRI high resolution induction tool is an electrical<br />
wireline tool that belongs to the induction logging family of<br />
tools. It records apparent conductivity of the subsurface<br />
formations. Data processing converts the measured<br />
conductivity into resistivity. The HRI tool works well in<br />
boreholes drilled with water, air, or oil. St<strong>and</strong>ard HRI tool<br />
presentation includes deep <strong>and</strong> medium resistivities derived<br />
from the raw conductivities. In conductive muds, a digitally<br />
focused resistivity log (DFL) <strong>and</strong> SP measurements are<br />
available.<br />
Applications<br />
Reliable Rt in resistivity environments from 0.2 to<br />
2,000 ohm-m provides improved estimates of water<br />
saturation<br />
Quantitative moveable hydrocarbon volumetric analysis<br />
<strong>and</strong> radial fluid distribution around the borehole when<br />
DFL is available<br />
High vertical resolution deep, medium conductivities<br />
<strong>and</strong> DFL logs enhance analysis in finely laminated<br />
reservoirs<br />
Distinguishes between conductive water-bearing <strong>and</strong><br />
hydrocarbon-bearing formations<br />
Provides estimate of invasion diameter <strong>and</strong> Rxo Features<br />
Sonde architecture consists of four transmitters <strong>and</strong> one<br />
receiver. The transmitter operates at 20 kHz<br />
The single receiver is a “three-coil” configuration for<br />
enhanced vertical resolution<br />
The tool measures both R <strong>and</strong> X components of the<br />
conductivities. X signals are used for skin effect<br />
correction<br />
The signal processing chain includes corrections for<br />
formation skin <strong>and</strong> shoulder bed effects to produce the<br />
deep (HDRS) <strong>and</strong> medium (HMRS) resistivities<br />
Length<br />
ft (m)<br />
33.3<br />
(10.2)<br />
The DFL provides a shallow focused resistivity<br />
measurement with a radial investigation of 15 in. The<br />
vertical resolution of the DFL closely matches that of the<br />
HRI tool induction curves<br />
A 1-ft vertical resolution improves estimates of Sw <strong>and</strong><br />
the hydrocarbon reserves in thinly laminated pays<br />
St<strong>and</strong>ard HRI log example showing deep <strong>and</strong> medium resistivities<br />
(Track 2) computed by correcting the raw conductivity data for skin,<br />
shoulder bed, <strong>and</strong> borehole effects.<br />
HRI High Resolution Induction Tool Specifications<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
Operating Pressure<br />
psi (bar)<br />
20,000<br />
(137.9)<br />
Operating Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
455<br />
(206.4)<br />
3-4 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
HDIL Hostile Dual Induction Log<br />
The HDIL hostile dual induction log tool is an open-hole<br />
electric wireline tool used to measure formation resistivity in<br />
high temperature, high pressure wells. The tool provides<br />
three resistivity measurements: short normal, medium<br />
induction, <strong>and</strong> deep induction. Also, SP electrodes are built<br />
into the sonde <strong>and</strong> provide an SP measurement in<br />
conductive mud systems. Flushed zone resistivity (R xo) is<br />
computed from the short normal measurement.<br />
The medium <strong>and</strong> deep induction array is hardware focused,<br />
<strong>and</strong> the measurements are derived from, respectively, 64440<br />
<strong>and</strong> 8ff34 coil configurations. The short normal has a spacing<br />
of 16 in.<br />
Applications<br />
The HDIL tool is specifically designed to provide reliable<br />
basic induction <strong>and</strong> resistivity measurements in<br />
extremely high temperature <strong>and</strong>/or high pressure wells<br />
The HDIL tool provides induction measurements in<br />
slimhole applications down to 4.75 in.<br />
Features<br />
Optimized for accurate induction <strong>and</strong> resistivity<br />
measurements in hostile conditions. Like the other<br />
HEAT suite tools, the HDIL tool is rated to operate in<br />
500°F <strong>and</strong> 25,000 psi environments<br />
Slim 2.75 in. tool diameter <strong>and</strong> relatively light tool<br />
weight facilitate safe operations in ultra deep, slim, or<br />
short-radius boreholes<br />
Fully combinable with other 500°F <strong>and</strong> 25,000 psi<br />
HEAT suite tools<br />
Post-processed environmental corrections are available<br />
An inversion for Rt , Rxo , <strong>and</strong> Di is available when the<br />
short normal is available (conductive muds)<br />
Length*<br />
ft (m)<br />
31.7<br />
(9.7)<br />
HDIL Hostile Dual Induction Log Specifications<br />
Diameter<br />
in. (mm)<br />
2.75<br />
(69.9)<br />
Maximum Pressure<br />
psi (Mpa)<br />
25,000<br />
(172.4)<br />
An HDIL log from a shaley s<strong>and</strong> sequence. The st<strong>and</strong>ard HDIL curves are<br />
presented <strong>and</strong> include a deep <strong>and</strong> medium induction as well as a short normal log.<br />
An SP log is supplied by an HDIL sonde-mounted electrode <strong>and</strong> is presented if the<br />
mud is sufficiently conductive.<br />
Maximum<br />
Temperature**<br />
°F (°C)<br />
Weight<br />
lb (kg)<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-5<br />
500<br />
(260)<br />
260<br />
(117.9)<br />
*The HDIL tool must be run with the isolation sub-assembly. The isolation sub-assembly is 1.9 ft (0.6 m) long <strong>and</strong><br />
is located between the cablehead <strong>and</strong> the telemetry section.<br />
**6 hour
DLL Dual Laterolog Service<br />
<strong>Halliburton</strong>'s proven DLL dual laterolog service provides a<br />
reliable means of measuring formation resistivity in<br />
conductive borehole fluids <strong>and</strong>/or where large contrasts exist<br />
between the formation <strong>and</strong> mud resistivities. The DLL<br />
service operates by focusing currents into the formation to<br />
produce a deep resistivity measurement (LLd) <strong>and</strong> a shallow<br />
resistivity measurement (LLs). The MSFL micro-<br />
spherically focused log is usually run in combination to<br />
provide a third shallow resistivity measurement. Together,<br />
these three measurements provide the resistivity profile<br />
around the borehole <strong>and</strong> permit the computation of R t in<br />
presence of invasion.<br />
Applications<br />
Provides accurate, high resolution shallow (LLs) <strong>and</strong> deep<br />
(LLd) resistivity measurements in high Rt /Rm conditions<br />
(>100) or when formation resistivity exceeds the limits<br />
for conventional induction tools (> 2,000 ohm-m)<br />
Quantitative assessment of Sw When run with the MSFL log, provides estimates of Rt, Rxo, <strong>and</strong> diameter of invasion<br />
Quantitative assessment of moveable water saturations<br />
(Sxo ) <strong>and</strong> moveable hydrocarbon volumes<br />
Acquires improved formation resistivity measurements in<br />
saline borehole fluids <strong>and</strong> in high Rt /Rm (>100) contrast<br />
logging conditions or when formation resistivity exceeds<br />
the limits of induction tools (>2000 ohm-m)<br />
Provides MSFL measurements to help delineate thin<br />
beds <strong>and</strong> provide estimates of Rxo Offers qualitative indication of permeable zones <strong>and</strong><br />
estimating invasion diameters (when run with the<br />
MSFL tool)<br />
Length<br />
ft (m)<br />
33.9<br />
(10.3)<br />
DLL Dual Laterolog Service Specifications<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
Features<br />
Rugged sonde construction <strong>and</strong> state-of-the-art<br />
electronics provide for accurate measurements of<br />
formation resistivity up to 40,000 ohm-m<br />
Dual electrode arrays <strong>and</strong> an automatic current-focusing<br />
technique<br />
The fundamental vertical resolution is 24 in. for both<br />
measurements which facilitates reservoir description of<br />
thinly bedded formations<br />
DLL log example from a carbonate-evaporite sequence showing deep <strong>and</strong><br />
medium laterolog curves presented along with the shallow MSFL log.<br />
3-6 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL9154<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
460<br />
(208.7)
MSFL Micro-Spherically Focused Log <strong>and</strong> Microlog (ML)<br />
The MSFL micro-spherically focused log <strong>and</strong> microlog<br />
(ML) tool is a pad-type version of the spherically focused log<br />
(SFL) that was developed to eliminate borehole effects <strong>and</strong><br />
achieve superior shallow resistivity measurements with high<br />
vertical resolution. Included with the MSFL tool is a ML<br />
sensor. The ML recorded 2-in. normal <strong>and</strong> 1.5-in. lateral<br />
resistivity measurements. The MSFL <strong>and</strong> ML tools are<br />
combined into one tool which can be run as a st<strong>and</strong>alone<br />
service or in combination. The pads are arranged on<br />
opposing, powered caliper arms which provide accurate<br />
measures of borehole size.<br />
Applications<br />
The MSFL tool provides measurements of Rxo in all types<br />
of conductive mud systems. Rxo is used quantitatively in<br />
computing Sxo <strong>and</strong> moveable water volumes<br />
The ML tool is sensitive to the presence of mudcake <strong>and</strong><br />
provides a qualitative indication of formation<br />
permeability<br />
Evaluation of thinly bedded s<strong>and</strong>/shale sequences<br />
Two powered caliper arms provide reliable estimates of<br />
borehole size<br />
Features<br />
The MSFL tool records resistivity with a vertical<br />
resolution of 8 in. <strong>and</strong> a depth of investigation of 3 in.<br />
The ML tool records resistivity with a vertical resolution<br />
of 2 in. <strong>and</strong> a depth of investigation of 1 in.<br />
Both the MSFL <strong>and</strong> ML tools, by virtue of being padtype<br />
devices, offer measurements relatively free of<br />
environmental effects. This makes them particularly well<br />
suited for operations in highly conductive (saltsaturated)<br />
mud systems<br />
Tool<br />
MSFL Tool<br />
ML with HFDT<br />
Assembly 1<br />
ML with SDLT<br />
Assembly 2<br />
Non-rubber versions of the MSFL <strong>and</strong> ML tools are<br />
available that provide superior resistance to gas<br />
absorption <strong>and</strong> better durability <strong>and</strong> run life over older<br />
rubber pad versions<br />
The tool can be run independently or in combination<br />
with other logging tools. When run in combination, the<br />
MSFL/ML tool can be placed anywhere in the toolstring<br />
MSFL Micro-Spherically Focused Log <strong>and</strong> Microlog (ML) Specifications<br />
Length<br />
ft (m)<br />
10.2<br />
(3.1)<br />
27.5<br />
(8.4)<br />
18.6<br />
(5.7)<br />
Diameter<br />
in. (mm)<br />
5<br />
(127)<br />
5<br />
(127)<br />
4.5<br />
(114.3)<br />
1 Weight, length, <strong>and</strong> diameter apply to the HFDT/Microlog assembly.<br />
2 Weight, length, <strong>and</strong> diameter apply to the SDLT/Microlog assembly.<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
350<br />
(176.7)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-7<br />
214<br />
(96.4)<br />
720<br />
(326.6)<br />
475<br />
(215.5)
HFDT High Frequency Dielectric Tool<br />
The HFDT high frequency dielectric tool is a pad-type<br />
electric logging tool used primarily in the determination of<br />
flushed-zone water saturation (S xo). The HFDT tool<br />
transmits a continuous 1,000 MHz electromagnetic wave<br />
into the formation <strong>and</strong> measures the propagated wave<br />
amplitude <strong>and</strong> phase with respect to the transmitted signal.<br />
The principle measurement objectives are to determine the<br />
complex dielectric constant of the formation. Depth of<br />
investigation ranges from 1 cm to about 10 cm.<br />
Applications<br />
Provides reliable Rxo measurements for determining<br />
flushed-zone water saturation (Sxo ) <strong>and</strong> moveable<br />
hydrocarbon volumes<br />
Determining irreducible water saturation (Swirr ) in oilbased<br />
muds<br />
Evaluation of thinly bedded s<strong>and</strong>/shale sequences<br />
Determination of the cementation exponent (m) when<br />
combined with other micro-resistivity logs<br />
Features<br />
Absolute <strong>and</strong> differential dielectric measurements are<br />
recorded, resulting in less sensitivity to borehole rugosity<br />
Uniquely measures both the incident <strong>and</strong> reflected phase<br />
<strong>and</strong> amplitude signal<br />
Phase-shift <strong>and</strong> attenuation measurements from three<br />
receivers for increased accuracy<br />
Automatic gain control permits good log quality across a<br />
wide range of formation resistivity<br />
Extendable pad sensor reduces borehole rugosity effects.<br />
An accelerometer curve <strong>and</strong> composite profiles of<br />
resistivity <strong>and</strong> dielectric curves give indications of<br />
irregular tool motion, mudcake buildup, <strong>and</strong> pad lift-off<br />
Length<br />
ft (m)<br />
27.5<br />
(8.4)<br />
Independent deployment of the pad <strong>and</strong> backup arm<br />
permit optimal alignment with other tools in the<br />
toolstring for more effective combination logging<br />
Works in fresh, salt-saturated, <strong>and</strong> oil-based mud<br />
systems, freshwater <strong>and</strong> most saltwater formations, <strong>and</strong><br />
in formations where water salinity is highly variable or<br />
unknown<br />
HFDT log computed on a s<strong>and</strong>stone matrix. Hydrocarbons are<br />
indicated when dielectric porosity FPHI falls below density/neutron<br />
porosity. In the above example, the high frequency dielectric clearly shows<br />
that the zones from 46 ft to 83 ft <strong>and</strong> 91 ft to 99 ft are hydrocarbon bearing<br />
while the zone from 132 ft to 142 ft is water filled.<br />
HFDT High Frequency Dielectric Tool Specifications<br />
Diameter<br />
in. (mm)<br />
4.75<br />
(120.7)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Maximum Temperature<br />
°F (°C)<br />
Weight<br />
lb (kg)<br />
3-8 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
320<br />
(160)<br />
720<br />
(326.6)
Imaging<br />
EMI Electrical Micro Imaging Service<br />
The EMI Electrical Micro Imaging service provides highly<br />
detailed, core-like images of the formations encountered by<br />
the borehole. These images are produced by measuring <strong>and</strong><br />
mapping formation micro-resistivity with each of the 150<br />
pad-mounted button electrodes on six independent arms.<br />
The current of each button is recorded as a curve <strong>and</strong><br />
sampled every 0.1-in. (120 samples/ft). These current<br />
variations are then converted to color or gray-scaled images.<br />
Conventional dipmeter information is embedded into the<br />
image data <strong>and</strong> is available for st<strong>and</strong>ard SED tool answer<br />
products. A navigation package is included in the EMI tool to<br />
provide accurate information on tool position <strong>and</strong><br />
orientation within the borehole.<br />
Consistent, direct pad contact with the borehole wall is<br />
essential to obtaining high quality borehole image data. By<br />
virtue of independent arm linkages <strong>and</strong> pad articulation,<br />
optimum pad contact can be maintained with a minimum of<br />
pad pressure even in rugose, washed-out, or non-circular<br />
boreholes. This results in accurate, sharp images, more<br />
complete borehole coverage, <strong>and</strong> a reduced dependence on<br />
corrections for irregular tool motion effects (speed<br />
corrections). In addition, the EMI service uses six<br />
independent arms, making it possible to acquire quality<br />
image data in non-optimal hole conditions.<br />
Applications<br />
Provides a variety of real-time <strong>and</strong> post-processing 2D<br />
<strong>and</strong> 3D image products to evaluate geological,<br />
petrophysical, <strong>and</strong> borehole properties<br />
Offers detailed structural, stratigraphic, <strong>and</strong><br />
sedimentological analysis for optimized offset well<br />
placement, completion tactics, <strong>and</strong> hydrocarbon<br />
depletion efficiency<br />
Allows thin bed delineation <strong>and</strong> improved net pay<br />
estimations<br />
Quantifies rock textures <strong>and</strong> electro-facies<br />
Permits 2D <strong>and</strong> 3D borehole geometry <strong>and</strong> breakout<br />
presentations from 6 caliper measurements as well as<br />
characterization <strong>and</strong> evaluation of secondary porosity<br />
Identifies orientation <strong>and</strong> connectivity of fracture<br />
systems<br />
Features<br />
Electric borehole technology has the capability of resolving<br />
features impossible to resolve using conventional logging<br />
tools. Small fractures, vugs, bedding planes, depositional<br />
features, thin beds, <strong>and</strong> rock texture changes provide<br />
significant insights that can impact reservoir exploration <strong>and</strong><br />
development.<br />
Associated Answer <strong>Products</strong><br />
SHIVA program<br />
AutoDip service<br />
TrendSetter service<br />
Texture-profile<br />
Manual dip picking<br />
Image interpretation<br />
Static (Track 2) <strong>and</strong> dynamic (Track 5) enhancement of an EMI<br />
borehole image showing a s<strong>and</strong>-shale sequence <strong>and</strong> the computed dips<br />
(Track 4) of the sedimentary strata. Vertical fractures (drilling artifacts)<br />
are also seen in the enhanced images. High resolution data can provide<br />
insight into the texture of the formation <strong>and</strong> reveal details conventional<br />
logs cannot.<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-9<br />
HAL9155
Equipment<br />
HAL9156<br />
Soft sediment deformation <strong>and</strong> slumping are captured on the<br />
electric image. The AutoDip program does a good job of<br />
capturing the dip reversals <strong>and</strong> h<strong>and</strong>ling the high angle dips.<br />
HAL9158<br />
EMI Tool Only<br />
EMI Toolstring<br />
Structural <strong>and</strong> stratigraphic dips are well represented in this<br />
example. Slumping above the base of the s<strong>and</strong> (3295) is<br />
evident <strong>and</strong> current bedding above give evidence of the<br />
depositional environment.<br />
EMI Electrical Micro Imaging Service Specifications<br />
Length<br />
ft (m)<br />
24<br />
(7.3)<br />
41<br />
(12.5)<br />
Diameter (minimum)<br />
in. (mm)<br />
5<br />
(127.0)<br />
5<br />
(127.0)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
Fine structural <strong>and</strong> stratigraphic details of a thinly bedded<br />
reservoir are captured in this borehole image. The<br />
automatically picked dips do an excellent job of capturing<br />
dip trend details. There are over 100 dips selected in this<br />
13-ft interval. H<strong>and</strong> picking would be tedious, time<br />
consuming, <strong>and</strong> perhaps discretionary.<br />
3-10 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL9157<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
496<br />
(225)<br />
350<br />
(176.7) N/A
XRMI X-Tended Range Micro Imager Tool<br />
This new electrical wireline borehole imaging tool is<br />
designed to obtain superior quality images even in high<br />
R t:R m environments. The exp<strong>and</strong>ed operating range of the<br />
XRMI X-tended range micro imager tool over<br />
conventional electrical imaging tools is achieved through its<br />
new, state-of-the-art 32 bit digital signal acquisition<br />
architecture combined with a large increase in available<br />
power for the excitation current (EMEX).<br />
As a result, the signal to noise ratio of the raw measurements<br />
is improved by a factor of up to five, <strong>and</strong> the dynamic range<br />
is exp<strong>and</strong>ed by a factor of up to three. The resulting images<br />
offer superior fidelity even in highly resistive formations<br />
(R t > 2000 ohm �m) or relatively salty borehole fluids<br />
(R m < 0.1 ohm �m).<br />
Besides the new electronics, the m<strong>and</strong>rel architecture derived<br />
from <strong>Halliburton</strong>’s highly successful EMI imaging tool<br />
greatly helps the XRMI tool generate superior quality<br />
borehole images. Pads mounted on six independently<br />
articulated arms help maintain pad contact in rugose,<br />
washed-out, elliptical, or highly deviated boreholes. Further,<br />
high sampling rate (120 samples/ft) <strong>and</strong> adequate borehole<br />
coverage (67% in 8.5 in. holes) help obtain high resolution<br />
pictures of the borehole walls.<br />
Applications<br />
Shows bedding dips that help rationalize the choice of<br />
next drilling location<br />
Chooses the sidewall core zones, formation testing zones,<br />
<strong>and</strong> perforation intervals accurately by integrating<br />
images with other open-hole logs<br />
Computes accurate high resolution net-to-gross<br />
Optimizes offset well placement by evaluating structural<br />
<strong>and</strong> stratigraphic features <strong>and</strong> bedding orientation<br />
Provides more accurate net-to-gross estimations in<br />
laminated shaly s<strong>and</strong>s <strong>and</strong> carbonates by delineating thin<br />
beds <strong>and</strong> laminations<br />
Rationalizes well stimulation <strong>and</strong> formation testing<br />
decisions by characterizing the secondary porosity (e.g.<br />
fractures <strong>and</strong> vugs) in reservoirs<br />
Optimizes drilling efficiency by evaluating <strong>and</strong> orienting<br />
borehole breakout<br />
Optimizes the completion tactics <strong>and</strong> reservoir<br />
management by providing characterization of rock<br />
texture <strong>and</strong> electro-facies<br />
a b c<br />
High resolution XRMI images showing the micro-textural geological<br />
details in the fabric of a limestone section in a test well from Permian<br />
Basin, West Texas: (a) vugular open porosity; (b) open natural fractures;<br />
<strong>and</strong> (c) stylolites. The R t:R m ratio exceeds 100,000 in this borehole.<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-11<br />
HAL13883<br />
HAL13882
Length<br />
ft (m)<br />
24.18<br />
(7.37)<br />
Maximum OD<br />
in. (cm)<br />
5<br />
(12.7)<br />
HAL13884<br />
Borehole coverage is 67% in 8.5 in. hole.<br />
An XRMI formation evaluation answer product generated by <strong>Halliburton</strong>’s<br />
proprietary software WXforecast. The first image track shows the static<br />
equalized image <strong>and</strong> the second image track exhibits the texture-enhanced high<br />
resolution image produced by the application texture-pro. Central dip-track<br />
shows the results of Auto-Dip service. The sharp change in the dip azimuths<br />
from west to east is interpreted to be due to slump faulting. The base of the<br />
channel s<strong>and</strong> is also a scoured surface.<br />
XRMI X-Tended Range Micro Imager Tool Specifications<br />
Minimum Hole Size<br />
in. (cm)<br />
6<br />
(15.240)<br />
Maximum Hole Size<br />
in. (cm)<br />
21<br />
(53.34)<br />
Maximum Pressure<br />
psi (Kpa)<br />
20,000<br />
(137 895)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
3-12 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
496<br />
(225)
OMRI Oil-Based Micro-Imager Tool<br />
The latest addition to <strong>Halliburton</strong>’s borehole imaging<br />
solutions is the OMRI tool for use in oil-based muds. The<br />
OMRI tool generates crisp, high-resolution digital images of<br />
the wellbore down to 1 in. of vertical resolution, instead of<br />
1 ft of vertical resolution that is available with conventional<br />
logging tools. The extra resolution makes thin bed pay <strong>and</strong><br />
other important features clearly visible.<br />
An advanced pad sensor generates six resistivity<br />
measurements per pad, each with a vertical resolution of 1 in.<br />
<strong>and</strong> a depth of investigation of about 3 in. Data is collected at<br />
120 samples per foot with a proprietary signal acquisition<br />
scheme optimized for rugose hole conditions. The pads are<br />
mounted on six independent caliper arms which yield true<br />
assessments of borehole shape <strong>and</strong> stress, useful in frac jobs<br />
<strong>and</strong> completion designs. The sensor pads are mounted on the<br />
caliper arms with unique two-axis of articulation. This<br />
facilitates improved pad contact, <strong>and</strong> thus improved images,<br />
in less than ideal borehole conditions. This combination of<br />
features provides unparalleled image fidelity over the widest<br />
possible range of logging conditions.<br />
HAL18834<br />
Applications<br />
High vertical resolution pay zone volumetrics (both<br />
fluids <strong>and</strong> minerals)<br />
Pay zone detection (in extreme thin bed / “low contrast”<br />
pay zones)<br />
Structural <strong>and</strong> stratigraphic dips<br />
Sedimentary features <strong>and</strong> textures<br />
Net-to-gross s<strong>and</strong> counts<br />
Identification of faults <strong>and</strong> unconformities<br />
Evaluation of sedimentary sequences <strong>and</strong> flow units<br />
Lithologic unit thickness<br />
Secondary porosity evaluation<br />
Sequence stratigraphy analysis<br />
Borehole stresses analysis<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-13
Features<br />
Identifies important reservoir characteristics, such as<br />
structural <strong>and</strong> stratigraphic dips, sedimentary geometry<br />
<strong>and</strong> texture, borehole stresses, <strong>and</strong> lithologic unit<br />
thickness<br />
Recognizes features beyond resolution of conventional<br />
logs, including permeability barriers, s<strong>and</strong> attributes,<br />
clasts, vugs, <strong>and</strong> more<br />
Quantifies important reservoir characteristics such as<br />
lithology, porosity, water saturation, permeability, fluid<br />
profile, <strong>and</strong> flow potential when integrated with other<br />
logs <strong>and</strong> well information<br />
Provides detailed, accurate pictures of the reservoir that<br />
answer key geological <strong>and</strong> petrophysical questions<br />
Identifies thin bed pay that cannot be seen with<br />
conventional logs, particularly in geologically younger,<br />
unconsolidated formations<br />
Helps increase success rate in multi-well developments<br />
by answering questions about sedimentology <strong>and</strong><br />
structural <strong>and</strong> stratigraphic analysis, which serve to<br />
enhance reservoir management decision making<br />
Optimizes design of completion programs in order to be<br />
more efficient <strong>and</strong> cost effective<br />
Length<br />
ft (m)<br />
27.54<br />
(8.39)<br />
Maximum OD<br />
in. (cm)<br />
5.5<br />
(13.97)<br />
Range of Mudcake<br />
Thickness Mudcake Resistivity<br />
OMRI Oil-Based Micro-Imager Tool Specifications<br />
Maximum Pressure<br />
psi (Kpa)<br />
20,000<br />
(137 895)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Borehole Conditions<br />
Recommended Logging Speed*<br />
Minimum Hole<br />
in. (cm)<br />
3-14 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
6.5<br />
(16.5)<br />
HAL18835<br />
Maximum Hole<br />
in. (cm)<br />
24<br />
(60.96)<br />
Borehole Fluids<br />
Weight<br />
lb (kg)<br />
760<br />
(344.73)<br />
High Data Rate Low Data Rate Tool Positioning Salt Fresh Oil Air<br />
0 - 0.25 in. > 10,000 ohm-m 30 ft/min (9.1 m/min) 20 ft/min (6.1 m/min) Centralized X<br />
*Slower logging speed may be required for low resistivity environments or poor borehole conditions.
CAST-V Circumferential Acoustic Scanning Tool-Visualization<br />
The CAST-V circumferential acoustic scanning toolvisualization<br />
is an ultrasonic tool that provides highresolution<br />
images in both fresh <strong>and</strong> oil-based drilling fluids.<br />
The tool’s interchangeable head rotates a full 360° <strong>and</strong><br />
contains a high-frequency acoustic transducer to provide a<br />
full 360° profile of the borehole. A second acoustic<br />
transducer is mounted in the scanner housing <strong>and</strong> is used to<br />
measure characteristics of the borehole fluid. A directional<br />
sub is provided to orient images to either the high side of the<br />
hole or to north. The image mode, run primarily in open<br />
hole, consists of 200 points horizontally by 40 samples/ft<br />
vertically. The CAST-V tool is designed to operate in<br />
conjunction with other DITS tools but must be run<br />
centralized in fluid filled boreholes.<br />
Applications<br />
Provides complete borehole imaging for accurate, precise<br />
formation evaluation<br />
Detailed structural, stratigraphic, <strong>and</strong> sedimentological<br />
analyses for optimized offset well placement, completion<br />
design, <strong>and</strong> hydrocarbon depletion efficiency<br />
Thin bed delineation <strong>and</strong> improved net pay estimations<br />
2D <strong>and</strong> 3D borehole geometry <strong>and</strong> breakout<br />
presentations from acoustic caliper measurements<br />
Features<br />
Resolves features impossible to resolve using<br />
conventional logging tools. Small fractures, vugs,<br />
bedding planes, depositional features, thin beds, <strong>and</strong><br />
rock texture changes provide significant insights that can<br />
impact reservoir exploration <strong>and</strong> development<br />
Real-time fluid cell measures both borehole fluid transit<br />
time <strong>and</strong> fluid impedance. The fluid transit time is used<br />
to correct the internal radius measurements made from<br />
the scanner head while the acoustic impedance<br />
measurement is used as a quality control monitor<br />
Associated Answer <strong>Products</strong><br />
Manual dip-picking<br />
Image interpretation<br />
CAST-V tool open-hole fractures example—3D projection with<br />
perspective view. Borehole breakout (in direction of minimum stress)<br />
normal to strike of fractures.<br />
CAST-V Circumferential Acoustic Scanning Tool-Visualization Specifications<br />
Length<br />
ft (m)<br />
17.9<br />
(5.5)<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-15<br />
HAL9159<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
316<br />
(143.3)
SED Six Arm Dipmeter<br />
The SED six arm dipmeter is an electric logging tool that<br />
provides data used to compute formation dip. It provides six<br />
formation micro-resistivity measurements, tool orientation<br />
data, <strong>and</strong> six caliper curves. The six micro-resistivity<br />
measurements are taken at 60° increments around the<br />
borehole. This data is then correlated to identify bedding <strong>and</strong><br />
other features in the formation.<br />
Applications<br />
Evaluate magnitude <strong>and</strong> direction of structural <strong>and</strong><br />
stratigraphic dip events for offset well placement,<br />
reservoir modeling, <strong>and</strong> reservoir management decisions<br />
Improved evaluation of thinly laminated s<strong>and</strong>/shale<br />
sequences<br />
Fracture detection<br />
Directional data to provide TVD, drift surveys, <strong>and</strong><br />
bottomhole location<br />
Caliper data as input to 2D <strong>and</strong> 3D borehole profile plots<br />
as well as integrated borehole volumetrics<br />
Features<br />
High resolution micro-resistivity measurements sampled<br />
at 0.1-in.<br />
Independent arm linkage <strong>and</strong> swiveled pads provide<br />
optimum pad contact with a minimum of pad force<br />
Tri-axial accelerometers <strong>and</strong> three magnetometers are<br />
employed to compute borehole drift, azimuth, <strong>and</strong><br />
corrections for tool rotation <strong>and</strong> irregular motion<br />
Available oil-based mud pads for acquiring dip logs in<br />
non-conductive drilling fluids<br />
Six independent caliper measurements describe borehole<br />
washout <strong>and</strong> breakout in precise detail<br />
Length<br />
ft (m)<br />
22.3<br />
(6.8)<br />
SED Six Arm Dipmeter Specifications<br />
Diameter<br />
in. (mm)<br />
4.5<br />
(114.3)<br />
Associated Answer <strong>Products</strong><br />
SHIVA program – st<strong>and</strong>ard analysis package to<br />
correlate raw micro-resistivity data <strong>and</strong> evaluate it for<br />
planar structural or sedimentological features. Results<br />
presented as vector (tadpole) plots. Available at the<br />
wellsite as well as in the computing centers<br />
Omnidip – module of SHIVA program uses the tool’s<br />
high sampling density to identify nonplanar surfaces <strong>and</strong><br />
describe current bedding characteristics <strong>and</strong> other<br />
nonplanar sedimentary structures<br />
Resmapa – borehole imaging program that interpolates<br />
between the six micro-resistivity curves to produce a<br />
color oriented image of structural <strong>and</strong> sedimentological<br />
features<br />
St<strong>and</strong>ard processed SED log showing the raw resistivity data <strong>and</strong><br />
results of dip analysis.<br />
3-16 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL9160<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
470<br />
(213.2)
Nuclear<br />
SDL Spectral Density Log<br />
The SDL spectral density log provides superior formation<br />
bulk density <strong>and</strong> borehole compensated photoelectric factor<br />
(Pe) measurements.<br />
Applications<br />
Determination of formation porosity<br />
Identification of formation lithology regardless of<br />
formation fluid type<br />
Indication of gas when used in combination with a<br />
neutron log<br />
Features<br />
Delineation of thinly bedded formations using the<br />
unfiltered Pe curve<br />
Field engineers perform precise calibration <strong>and</strong> wellsite<br />
checks<br />
Curves indicating data quality are displayed on a<br />
computer screen in real-time <strong>and</strong> are recorded on the log<br />
Advanced correction algorithm is applied to density data<br />
Rigid tungsten pad incorporates a 1.5-curie cesium-137<br />
source <strong>and</strong> two high-efficiency scintillation detectors<br />
designed to maintain high gamma counts<br />
Rugged construction <strong>and</strong> advanced gain stabilization<br />
help maintain measurement integrity under varying<br />
temperature conditions<br />
Combinable with a complete family of tools that<br />
operates under the DITS digital interactive telemetry<br />
system<br />
CALIPER<br />
INCHES<br />
GAMMA<br />
API<br />
Typical Field Output of the SDL Tool<br />
Mineral Identification Plot<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-17<br />
HAL9374<br />
6<br />
0<br />
-4.5<br />
4.5<br />
Quartz<br />
QS<br />
QL<br />
16<br />
200<br />
0.5<br />
-0.5<br />
X250<br />
X300<br />
X350<br />
X400<br />
X450<br />
Dolomite<br />
2.0<br />
Pe c<br />
rb<br />
0 10 -0.25<br />
HAL323<br />
Dr<br />
3.0<br />
0.25<br />
Calcite
Associated Answer <strong>Products</strong><br />
The wellsite answer product is apparent bulk density of<br />
the formation <strong>and</strong> borehole compensated photoelectric<br />
factor<br />
Bulk density or density porosity data is used with other<br />
open-hole sensors as input to <strong>Halliburton</strong>’s mineralogy,<br />
open-hole, <strong>and</strong> cased-hole saturation analysis to provide<br />
a complete formation evaluation product. These include:<br />
Length<br />
ft (m)<br />
19.3<br />
(5.9)<br />
SDL Spectral Density Log Specifications<br />
Diameter<br />
in. (mm)<br />
4.5<br />
(114.3)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
– ULTRA multi-mineral evaluation program<br />
– CORAL complex lithology analysis<br />
–LARA laminated reservoir analysis<br />
– SASHA shaly s<strong>and</strong> analysis<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
420<br />
(190.5)<br />
3-18 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
DSN Dual-Spaced Neutron Tool<br />
The DSN dual-spaced neutron tool is a thermal neutron<br />
tool designed to measure formation porosity from neutronnuclei<br />
interactions. Neutron porosity logs provide total fluid<br />
information for use with resistivity logs <strong>and</strong>/or pulsed<br />
neutron logs in determining formation water saturation.<br />
They can be combined with density logs to provide an<br />
indication of formation gas saturation <strong>and</strong> also with density<br />
<strong>and</strong>/or sonic logs to provide indications of formation<br />
lithology. In open holes, the DSN tool is usually combined<br />
with the SDLT spectral density logging tool <strong>and</strong> the<br />
NGRT natural gamma ray tool. In cased holes, the<br />
DSN tool is usually combined with the NGRT tool <strong>and</strong><br />
DITS casing collar locator.<br />
The DSN tool consists of an instrument section housing the<br />
electronics, two He3 detectors, <strong>and</strong> a source sub housing an<br />
americium-beryllium source which generates fast neutrons<br />
that penetrate the formation at an initial energy of 4.6 MeV.<br />
Thermal neutron tools are not as limited by the spacing <strong>and</strong><br />
depth of investigation problems associated with epithermal<br />
neutron tools. Since thermal neutrons are detected, count<br />
rates are much higher than for epithermal neutrons.<br />
However, thermal neutron detectors are more sensitive to<br />
lithology <strong>and</strong> are affected by borehole <strong>and</strong> formation salinity.<br />
The dual detector method is used to compensate for these<br />
environmental effects.<br />
Applications<br />
Gas detection<br />
Porosity<br />
Lithology<br />
Features<br />
Detector array contains two helium proportional<br />
counters<br />
Optimized detector spacing, advanced calibration<br />
methods, <strong>and</strong> greater counting rates<br />
Faster log runs<br />
Delineation of thin-bed formations with enhanced<br />
vertical resolution (EVR) available in real-time or in<br />
post-processing<br />
A combination of logging tools can be run to identify<br />
lithology, reveal gas zones, <strong>and</strong> calculate shale volumes<br />
In this DSN log example, the subject well was logged twice. The<br />
resulting near/far ratio curves <strong>and</strong> the calculated porosity curves are<br />
overlaid to illustrate the high repeatability of DSN tool<br />
porosity measurements.<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-19<br />
HAL1664
Associated Answer <strong>Products</strong><br />
Wellsite answer product is the neutron porosity NPHI<br />
Neutron porosity data is also used with other open-hole<br />
sensors as input to <strong>Halliburton</strong>’s mineralogy, open-hole,<br />
<strong>and</strong> cased-hole saturation analysis to provide a complete<br />
formation evaluation product. These include:<br />
Length<br />
ft (m)<br />
10.25<br />
(3.1)<br />
– ULTRA multi-mineral evaluation program<br />
– CORAL complex lithology analysis<br />
–LARA laminated reservoir analysis<br />
– SASHA shaly s<strong>and</strong> analysis<br />
DSN Dual-Spaced Neutron Tool Specifications<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
196<br />
(88.9)<br />
3-20 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
DSEN Dual-Spaced Epithermal Neutron Log Tool<br />
The DSEN dual-spaced epithermal neutron log tool is a<br />
subsurface logging tool that provides a measurement of<br />
epithermal neutron porosity. It is used primarily in air-filled<br />
wells or in fluid-filled wells where shales <strong>and</strong>/or formation<br />
salinity adversely affect thermal neutron measurements. In<br />
open boreholes, the DSEN tool is usually combined with the<br />
SDLT spectral density logging tool <strong>and</strong> the NGRT<br />
natural gamma ray tool.<br />
Applications<br />
Neutron porosity measurements in water or gas filled<br />
boreholes<br />
Gas detection in the formation or in filled wellbores<br />
when combined with density measurements<br />
Porosity curve measurements that are less affected by<br />
thermal neutron absorbers in shale, such as boron <strong>and</strong><br />
gadolinium<br />
Features<br />
Less affected by formation water salinity<br />
Combinable with other tools<br />
Optimized dual neutron detector design combines twodetector<br />
responses for enhanced accuracy<br />
Uses a steady-state neutron generating source<br />
(radioactive americium-beryllium, AmBe) <strong>and</strong> two<br />
epithermal neutron detectors to investigate formation<br />
porosity<br />
Provides reliable porosity measurements even in air, gas,<br />
<strong>and</strong> foam-filled boreholes<br />
Provides consistent, repeatable data over entire porosity<br />
range<br />
Requires minimum corrections in high-temperature<br />
environments, such as steamfloods <strong>and</strong> high-porosity<br />
formations<br />
Associated Answer <strong>Products</strong><br />
Epithermal neutron porosity (wellsite)<br />
Neutron porosity data is also used with other open-hole<br />
sensors as input to <strong>Halliburton</strong>’s mineralogy, open-hole,<br />
<strong>and</strong> cased-hole saturation analysis to provide a complete<br />
formation evaluation product. These include:<br />
– ULTRA multi-mineral evaluation program<br />
– CORAL complex lithology analysis<br />
–LARA laminated reservoir analysis<br />
– SASHA shaly s<strong>and</strong> analysis<br />
DSEN log computed assuming a limestone matrix. The bottom of the<br />
well is liquid filled. From x534 to the top, the well is air filled. Formation<br />
gas is indicated when the density porosity becomes greater than the<br />
neutron porosity. This log reveals good gas zones from x586 to x427.<br />
DSEN Dual-Spaced Epithermal Neutron Log Tool Specifications<br />
Length<br />
ft (m)<br />
7.25<br />
(2.2)<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-21<br />
HAL1663<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
170<br />
(77.1)
CSNG Compensated Spectral Natural Gamma Ray<br />
The CSNG compensated spectral natural gamma ray tool<br />
measures the gamma ray spectrum from 0 to 3,000 keV. The<br />
tool uses full-spectrum processing to provide precise <strong>and</strong><br />
accurate logs of potassium, uranium, <strong>and</strong> thorium<br />
concentrations. Measurement precision curves <strong>and</strong> tool<br />
diagnostics help validate logging data quality.<br />
The CNSG tool's unique stabilizer system differentiates it<br />
from the competition by compensating for temperature<br />
related drift in the gamma ray energy gain <strong>and</strong> offset<br />
conversion. The full-spectrum processing performs<br />
additional refinement of the energy calibration <strong>and</strong><br />
compensates for variations in detector resolution.<br />
Another unique feature of the CSNG tool is its ability to<br />
provide real-time outputs corrected for the borehole<br />
environment <strong>and</strong> converted to st<strong>and</strong>ard conditions<br />
(8.625-in. borehole, freshwater in borehole, no casing, <strong>and</strong><br />
tool eccentered).<br />
Estimates of borehole potassium concentration <strong>and</strong><br />
photoelectric absorption made during the log are helpful to<br />
confirm real-time corrections or to apply corrections in a recomputation<br />
mode. Also, removal of borehole potassium<br />
signal produces accurate total gamma ray <strong>and</strong> elemental<br />
yields in potassium muds.<br />
Applications<br />
Detection of producible zones<br />
Determine clay types, volumes, <strong>and</strong> cation exchange<br />
capacity using elemental concentration data <strong>and</strong> CLAMS<br />
clay <strong>and</strong> matrix analysis post-processing analysis<br />
Features<br />
Measures <strong>and</strong> records energy of individual gamma rays<br />
Elemental yield calculations are insensitive to<br />
photoelectric absorption in barite muds or other high-Z<br />
materials<br />
Filtering technique improves the statistical precision of<br />
the elemental yields<br />
Forms a spectrum of gamma energies indicating the<br />
number of gamma rays recorded at each energy level<br />
0 to 3 MeV spectrum facilitates determination of<br />
potassium, uranium, <strong>and</strong> thorium weight concentrations<br />
in the formation<br />
Reduced cross-correlation among elemental yields<br />
Associated Answer <strong>Products</strong><br />
Output from the CSNG spectral processing includes<br />
total gamma ray <strong>and</strong> elemental concentrations of<br />
potassium, uranium, <strong>and</strong> thorium<br />
Clay typing, volumes, <strong>and</strong> cation exchange capacity can<br />
be compared using CLAMS analysis software<br />
CSNG log with gamma ray contributions from thorium, potassium, <strong>and</strong><br />
uranium<br />
3-22 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
Housing<br />
Titanium<br />
Low Z<br />
LOGIQ ® CSNG Compensated Spectral Natural Gamma Ray Specifications<br />
Makeup Length<br />
ft (m)<br />
14.9<br />
(4.5)<br />
12.9<br />
(3.9)<br />
Diameter<br />
in. (mm)<br />
3.625<br />
(92.1)<br />
3.625<br />
(92.1)<br />
*Please refer to the CSNG Pressure Rating Chart below.<br />
HAL23446<br />
Maximum Pressure*<br />
psi (Mpa)<br />
Maximum Temperature<br />
°F (°C)<br />
Weight<br />
lb (kg)<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-23<br />
14,000<br />
(96.5)<br />
8,000<br />
(55.2)<br />
350<br />
(176.7)<br />
275<br />
(135)<br />
271<br />
(122.9)<br />
260<br />
(117.9)
Acoustics<br />
BSAT Borehole Compensated Sonic Array Tool<br />
<strong>Halliburton</strong>'s BSAT service integrates two monopole<br />
transmitters with an array of five receivers. This tool<br />
configuration provides borehole compensation of the P-wave<br />
measurement. The full waveform data is digitally recorded<br />
for each receiver, thus permitting advanced data analysis <strong>and</strong><br />
quality control for waveform amplitude, slowness, <strong>and</strong><br />
arrival time in both open-hole <strong>and</strong> cased-hole applications.<br />
The BSAT tool is over 12 ft shorter than many other acoustic<br />
logging tools. While not compromising data quality, the<br />
reduction in tool length helps speed up rig-up <strong>and</strong> rig-down<br />
times, especially when lubricator <strong>and</strong> pressure control<br />
equipment are required.<br />
The P-wave slowness is obtained using a robust waveform<br />
cross correlation coherency process which utilizes the<br />
waveform data from the entire receiver array. The process<br />
evaluates many attributes of the waveform data before<br />
selecting, in real time, the acoustic velocities of the<br />
formation.<br />
The BSAT tool can also be used for 3-ft to 5-ft CBL-VDL<br />
measurements <strong>and</strong> can be run in combination with any IQ<br />
tool services.<br />
Applications<br />
P-wave slowness used for sonic porosity determination<br />
Time-to-depth correlation<br />
Synthetic seismograms<br />
Identification of pore pressure changes<br />
3-ft to 5-ft CBL-VDL measurement<br />
Instantaneous waveform attributes<br />
Features<br />
Waveforms can be recorded at high logging speeds<br />
The P-wave slowness is obtained using a robust<br />
waveform cross correlation semblance process<br />
Downhole digitization helps eliminate the transmission<br />
noise <strong>and</strong> improve signal-to-noise ratio. Compression<br />
technique allows high uplink data transfer rate<br />
Length<br />
ft (m)<br />
15.83<br />
(4.82)<br />
Can be used as CBL tool in combination with any<br />
LOGIQ® cased-hole services<br />
Gamma ray, VpVs, <strong>and</strong> caliper presented in Track 1.<br />
Compressional <strong>and</strong> refracted shear are presented in Track 2.<br />
Semblance with compressive <strong>and</strong> shear slowness overlaid on<br />
the semblance image are presented in Track 3.<br />
BSAT Borehole Compensated Sonic Array Tool Specifications<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
318<br />
(144.4)<br />
3-24 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
WaveSonic ® Tool<br />
The WaveSonic® crossed dipole sonic tool provides<br />
simultaneous monopole, XX dipole, <strong>and</strong> YY dipole sonic<br />
measurements. The dipole flexural wave propagation allows<br />
for the measurement of shear wave slowness in virtually all<br />
formation conditions. The compressional P-wave slowness,<br />
refracted shear wave slowness, <strong>and</strong> Stoneley wave properties<br />
are obtained from the monopole data. The shear wave<br />
slowness in two orthogonal directions can be obtained in<br />
real- time from the XX <strong>and</strong> YY dipole data. The WaveSonic<br />
tool is combinable with all st<strong>and</strong>ard open <strong>and</strong> cased-hole<br />
tool services. The WaveSonic tool requires a liquid filled<br />
borehole <strong>and</strong> can be used in freshwater, saltwater, or oilbased<br />
mud systems. The robust mechanical design of this<br />
tool allows for drillpipe conveyed logging, <strong>and</strong> it is not<br />
limited to the bottom of the toolstring. A hostile WaveSonic<br />
version is available for high-temperature <strong>and</strong> high-pressure<br />
applications.<br />
The shear wave slowness in the XX <strong>and</strong> YY directions <strong>and</strong> the<br />
monopole P-wave slowness are the basic well site<br />
deliverables. The tool has 32 broadb<strong>and</strong> receivers, arranged<br />
in eight rings of four receivers, to provide high-quality<br />
waveform data. The tool provides 96 waveforms (32<br />
monopole, 32 YY dipole, <strong>and</strong> 32 XX dipole) for each firing<br />
cycle, which are recorded by the surface system. The fast <strong>and</strong><br />
slow shear wave travel times are obtained with advanced<br />
waveform processing methods in <strong>Halliburton</strong>'s reservoir<br />
evaluation services centers, strategically located throughout<br />
the world.<br />
From the fast <strong>and</strong> slow shear wave travel times, <strong>and</strong> their<br />
orientation in the formation, the minimum <strong>and</strong> maximum<br />
principal stresses <strong>and</strong> stress field orientation can be obtained<br />
by combining oriented slowness data with overburden <strong>and</strong><br />
analysis, wellbore stability, <strong>and</strong> production enhancement<br />
treatment design.<br />
Natural gamma ray <strong>and</strong> caliper are presented in Track 1. Semblance<br />
quality data is presented in the depth track. The dipole X travel time,<br />
dipole Y travel time, <strong>and</strong> monopole P-wave travel time are presented<br />
in Track 2. Monopole semblance with the compressive wave slowness<br />
overlaid on the semblance image are presented in Track 3. The dipole<br />
X semblance with the XX shear wave slowness overlaid on the<br />
semblance image are presented in Track 4. The dipole Y semblance<br />
with the YY shear wave slowness overlaid on the semblance image are<br />
presented in Track 5.<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-25
Sonic anisotropy analysis provides the fast <strong>and</strong> slow shear<br />
wave travel times as a simultaneous solution of 64 waveforms<br />
(32 XX <strong>and</strong> 32 YY). Anisotropy <strong>and</strong> its orientation can be<br />
used to determine the minimum horizontal stress <strong>and</strong> the<br />
orientation of natural fractures. The sonic attributes of<br />
slowness, amplitude, <strong>and</strong> frequency content can be used for<br />
identification of fractures <strong>and</strong> compressive fluids <strong>and</strong> to<br />
measure various geomechanical properties. The fast <strong>and</strong> slow<br />
shear wave travel times <strong>and</strong> their orientation, combined with<br />
P-wave slowness, allows for better 3D seismic analysis.<br />
Applications<br />
Determine fast <strong>and</strong> slow wave travel times <strong>and</strong><br />
orientation in the formation<br />
Calculate minimum <strong>and</strong> maximum principal stresses<br />
<strong>and</strong> stress field orientation<br />
Porosity estimation<br />
Fracture identification<br />
Permeability (mobility) estimation<br />
AVO calibration<br />
Synthetic seismogram<br />
Features<br />
Programmable-frequency sources to minimize effects of<br />
near-wellbore alteration<br />
Length<br />
ft (m)<br />
Tool<br />
Version<br />
20 kpsi<br />
Tool<br />
30 kpsi<br />
Tool<br />
34.0<br />
(10.3)<br />
Length<br />
ft (m)<br />
40.9<br />
(12.4)<br />
40.9<br />
(12.4)<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
WaveSonic ® Tool Specification<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Broadb<strong>and</strong> eight-level, quad receiver array for highquality<br />
waveform data<br />
All 96 waveforms for each set of transmitter firings are<br />
recorded at the surface for advanced waveform<br />
processing techniques<br />
Combinable with all open-hole tools, including MRIL®<br />
<strong>and</strong> RDT tools <strong>and</strong> services<br />
Associated Answer <strong>Products</strong><br />
Shear slowness anisotropy analysis<br />
RockXpert2 s<strong>and</strong> production <strong>and</strong> fracture strength<br />
analysis<br />
FracXpert fracture stimulation zoning analysis pore<br />
pressure data information is vital for geo-mechanical<br />
Instantaneous waveform attributes<br />
Stoneley derived permeability<br />
Stoneley reflection analysis<br />
Formation stress, borehole stability, <strong>and</strong> s<strong>and</strong>ing<br />
potential<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Hostile WaveSonic ® Tool Specification<br />
Diameter<br />
in. (mm)<br />
3.13<br />
(79.4)<br />
3.13<br />
(79.4)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
30,000<br />
(206.8)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
500<br />
(260.0)<br />
500<br />
(260.0)<br />
Weight<br />
lb (kg)<br />
520<br />
(236.3)<br />
Weight<br />
lb (kg)<br />
595<br />
(269.9)<br />
720<br />
(326.6)<br />
3-26 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
FWS Full Wave Sonic Tool<br />
The FWS tool provides compressional wave, refracted<br />
shear wave, <strong>and</strong> Stoneley wave properties of downhole<br />
formations for a wide range of petrophysical, geological, <strong>and</strong><br />
geophysical applications. To minimize the number of logging<br />
trips required for complete formation evaluation, the FWS<br />
tool is compatible with all DITS logging tool strings. A<br />
liquid-filled borehole is required for sonic logging <strong>and</strong> can be<br />
used in fresh, salt, or oil-based mud systems.<br />
The long transmitter-to-receiver offset allows for the<br />
acquisition of borehole sonic data beyond the effects of any<br />
near-wellbore altered region. This long offset also allows for<br />
the acquisition of high-quality sonic data in enlarged<br />
boreholes where critical angle effects would affect sonic tools<br />
with short transmitter-to-receiver offsets.<br />
The information obtained from the FWS tool is plotted in<br />
three separate log presentations:<br />
Slowness presentation – compressional slowness <strong>and</strong><br />
refracted shear slowness, velocity ratio, <strong>and</strong> time-depth<br />
integration of the compressional <strong>and</strong> shear travel times,<br />
<strong>and</strong> other logging data such as gamma ray <strong>and</strong> caliper<br />
Quality presentation – indicators which establish<br />
confidence levels for the slowness processing, including<br />
compressional slowness <strong>and</strong> semblance coherency <strong>and</strong><br />
refracted shear <strong>and</strong> semblance quality gain curves for<br />
each receiver<br />
Waveform presentation – waveforms from all four<br />
receivers can be presented. Gain curves reflecting the<br />
gain applied to the waveform by the automatic gain<br />
control (AGC) circuit, <strong>and</strong> correlation curves, including<br />
gamma ray <strong>and</strong> caliper information<br />
The FWS tool can be run in the cased-hole environment to<br />
obtain sonic properties through casing. Acoustic coupling of<br />
the pipe-to-formation is required for cased-hole<br />
applications.<br />
Applications<br />
Identify wave properties of downhole formations<br />
Acquisition of borehole sonic data<br />
The natural gamma ray, X-X caliper, Y-Y caliper, P-wave travel time <strong>and</strong><br />
P-wave semblance quality are presented in Track 1. The monopole<br />
waveform data is presented in Track 2 in the MicroSeismogram format<br />
(X-Z) <strong>and</strong> in an X-Y waveform presentation in Track 3.<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-27<br />
HAL9170
Features<br />
Long transmitter-to-receiver offsets <strong>and</strong> 1 ft<br />
receiver-to-receiver spacings<br />
Detection of signals at all receivers for each transmitter<br />
pulse ensures constant source characteristics<br />
Automatic gain control of each receiver preserves signal<br />
amplitude<br />
Downhole digitizing helps eliminate transmission noise<br />
<strong>and</strong> allows broadb<strong>and</strong> frequency response<br />
Low-frequency response allows detection of low<br />
frequency Stoneley waves <strong>and</strong> multiple Δt measurements<br />
per depth interval<br />
Continuous uninterrupted recording of full waveform<br />
signals<br />
Records various types of information including tool<br />
data, quality curves, <strong>and</strong> final results<br />
Operator-selectable multiple modes of tool operation,<br />
digitally recorded waveform data, <strong>and</strong> improved porosity<br />
estimates using both Δtc <strong>and</strong> Δts Length<br />
ft (m)<br />
28.6<br />
(8.7)<br />
FWS Full Wave Sonic Tool Specifications<br />
Diameter<br />
in. (mm)<br />
3.625<br />
(92.1)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Lithology identification by means of velocity ratio, Δts/ Δtc, <strong>and</strong> location of gas zones, even in poor hole<br />
conditions <strong>and</strong> cased holes<br />
Indication of permeability variations with depth from<br />
Stoneley wave attenuation <strong>and</strong> slowness<br />
Detection of naturally fractured zones, determination of<br />
rock elastic constants, <strong>and</strong> estimation of formation<br />
strength <strong>and</strong> least horizontal stress<br />
Prediction of vertical extent of hydraulic fractures<br />
Improved vertical resolution for detection of thinner<br />
beds (Beds as thin as 3 in. can be identified with the t<br />
curves)<br />
Calculates sonic porosity from P-wave slowness <strong>and</strong> can<br />
determine secondary porosity by combining sonic<br />
porosity with neutron <strong>and</strong> density porosity data<br />
Time-to-depth correlation for seismic correlation<br />
Combining sonic slowness data with formation density<br />
data is the required input information needed for<br />
synthetic seismograms<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
460<br />
(208.7)<br />
3-28 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
NMR<br />
MRIL-XL <strong>and</strong> MRIL ® -Prime Magnetic<br />
Resonance Image Logging Tools<br />
The MRIL-XL tool is the latest family member of<br />
<strong>Halliburton</strong>'s wireline NMR logging tools. Both the MRIL-<br />
XL <strong>and</strong> MRIL®-Prime should be considered the first choices<br />
for primary formation evaluation in open holes.<br />
NMR logging answers the four basic, critical questions all<br />
well operators must answer to underst<strong>and</strong> the economics of a<br />
newly drilled prospect:<br />
Has the well penetrated reservoir rock? (What is the total<br />
<strong>and</strong> effective porosity in a complex lithology<br />
environment?)<br />
What types of fluids (hydrocarbons) are present in the<br />
reservoir <strong>and</strong> how are they distributed?<br />
What is the ability of the reservoir to produce these<br />
hydrocarbons, i.e. will they flow in this type of<br />
formation? (What is the permeability?)<br />
Will there be associated water production (BVI/FFI)?<br />
The MRIL-XL <strong>and</strong> MRIL-Prime tools utilize the very same<br />
principles as medical MRI by directly measuring the<br />
magnetic resonance of hydrogen atoms in fluids. Amplitude<br />
of the measured signals gives porosity, whereas the actual<br />
signature carries information on rock properties <strong>and</strong> fluid<br />
characteristics.<br />
Applications<br />
The MRIL® tools are used in open-hole logging programs to:<br />
Obtain minerology-independent measurements of<br />
porosity. The MRIL tools truly measure the amount of<br />
fluid in the pore space <strong>and</strong> do not measure rock matrix.<br />
Unlike density, neutron, or sonic porosity devices, which<br />
require accurate matrix <strong>and</strong> fluid-density or Δt-matrix<br />
<strong>and</strong> Δt fluid to compute porosity, the MRIL tools are<br />
uniquely a minerology-independent porosity tool(s),<br />
yielding clay-bound water porosity, irreducible porosity<br />
(i.e. volume of bound fluid), free-fluid porosity, <strong>and</strong> total<br />
porosity<br />
Provide a permeability profile along the well. (Note that<br />
st<strong>and</strong>ard perm values are not calibrated; this requires<br />
integration with core data.)<br />
Provide fluid-typing (gas-oil-water), find fluid contacts,<br />
identify changes in oil viscosity<br />
Identify low-resistivity <strong>and</strong>/or low-contrast pay zones<br />
MRIL®-Prime Service<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-29<br />
HAL18923<br />
HAL1716<br />
MRIL-XL Service
Features<br />
As an eccentered NMR tool, the MRIL-XL signal<br />
penetration into the formation is effectively increased in<br />
large boreholes, <strong>and</strong> the effects of drilling mud are<br />
eliminated. MRIL-XL service is available with a st<strong>and</strong>ard<br />
6-in. sonde to accommodate holes sizes from 7.875-in. to<br />
>12.25-in. <strong>and</strong> is especially effective in large deviated<br />
boreholes. MRIL®-Prime is available in two sizes (slim sonde<br />
has 4.875-in. OD <strong>and</strong> st<strong>and</strong>ard sonde has 6-in. OD) to<br />
accommodate hole sizes from 5.875-in. to 12.25-in. Both<br />
MRIL services may be operated at up to 9 RF-frequencies—<br />
allowing data acquisition to be fast <strong>and</strong> efficient.<br />
Each frequency creates an independent volume of fluids<br />
in the formation, which allows the tool to log<br />
considerably faster than any single frequency NMR tool<br />
Both MRIL services can acquire simultaneous T1 <strong>and</strong> T2 logs <strong>and</strong> all MRIL services have maximum temperature<br />
ratings of 350°F<br />
Through-wire <strong>and</strong> switching sub adapters offer ultimate<br />
combinability with other <strong>Halliburton</strong> tools <strong>and</strong><br />
competitor tools<br />
Compatible with drillpipe or tubing conveyed type<br />
logging systems in highly deviated wells<br />
Accurately measures porosity in mixed mineralogy<br />
reservoirs<br />
Improves completion success in low-permeability<br />
reservoirs<br />
Identifies pay zones in laminated, fine-grained s<strong>and</strong>, <strong>and</strong><br />
shale formations<br />
Increases access to reserves by providing complete <strong>and</strong><br />
accurate analyses of low resistivity/low-contrast intervals<br />
Identifies zones of water-free production<br />
Sonde<br />
in.<br />
6.0<br />
Sonde<br />
in.<br />
6<br />
4.875<br />
Multi-frequency capability allows operators to acquire<br />
much more accurate data by combining the<br />
measurements made in each volume (at each different<br />
frequency)<br />
Only product to allow combining of different<br />
measurements probing different NMR properties of the<br />
fluids <strong>and</strong> formation in one single pass—a major step<br />
forward in fluid identification <strong>and</strong> quantification<br />
Has successfully pioneered the discovery of oil in zones<br />
which triple-combo has traditionally bypassed, leading<br />
to increased production of reserves <strong>and</strong> some spectacular<br />
discoveries in even mature production areas<br />
These huge amounts of reservoir information from a single<br />
device are extremely valuable for optimizing stimulation <strong>and</strong><br />
completion programs, thereby optimizing the productivity<br />
of each well drilled.<br />
Associated Answer <strong>Products</strong><br />
MRIAN MRI analysis – an integrated analysis which<br />
incorporates MRIL porosity from T1 <strong>and</strong>/or T2 plus<br />
resistivity data in the dual-water model<br />
TDA time domain analysis – a MRIL only fluids <strong>and</strong><br />
porosity analysis derived from analysis of the raw NMR<br />
echo train data only<br />
DTW dual wait time analysis – an analysis of<br />
hydrocarbon type or types found within each reservoir.<br />
Obtained by operating the MRIL service using a short<br />
<strong>and</strong> long Tw (wait time, such as 1s <strong>and</strong> 12s) in a single<br />
logging pass<br />
DTE dual echo time analysis – an analysis of<br />
hydrocarbon or other fluids within each reservoir.<br />
Obtained by operating the MRIL service using two<br />
different Te (inter-echo spacing, such as a short Te of<br />
1.2ms <strong>and</strong> a longer Te of 6ms or longer)<br />
MRIL ® -Prime Magnetic Resonance Image Logging Tool Specifications<br />
Length<br />
ft (m)<br />
52.9<br />
(16.1)<br />
50.4<br />
(15.4)<br />
Length<br />
ft (m)<br />
45.7<br />
(13.49)<br />
Diameter<br />
in. (mm)<br />
6.00<br />
(152.4)<br />
4.875<br />
(123.8)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
MRIL-XL Service Specifications<br />
Diameter<br />
in. (mm)<br />
6.00<br />
(152.4)<br />
Maximum Pressure<br />
psi (MPa)<br />
20,000<br />
(137.9)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
350<br />
(176.7)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
1,475<br />
(669.1)<br />
1,275<br />
(578.3)<br />
Weight<br />
lb (kg)<br />
3-30 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
1,600<br />
(726)
MRILab ® Magnetic Resonance Image Fluid Analyzer<br />
<strong>Halliburton</strong>'s patented MRILab® service is another<br />
breakthrough development of nuclear magnetic resonance<br />
imaging technology for oil <strong>and</strong> gas operators. The service<br />
provides laboratory-quality fluids measurements at reservoir<br />
conditions in real time by directly measuring the magnetic<br />
resonance parameter T 1. Because contaminates mixed with<br />
crude oil modulate the T 1 response, these measurements can<br />
be interpreted to determine when a clean sample can be<br />
taken <strong>and</strong> saved in <strong>Halliburton</strong>'s RDT reservoir description<br />
tool sample chambers. This ability to provide downhole<br />
laboratory-quality fluid measurements makes the MRILab<br />
service an integral component of the RDT tool.<br />
The MRILab service allows operators to measure relaxation<br />
times on reservoir fluids in-situ at true reservoir<br />
conditions—an important industry first. The measured T 1,<br />
T 2, <strong>and</strong> the self-diffusion coefficient (D) of the reservoir<br />
fluids tie directly into important fluid characteristics such as<br />
viscosity <strong>and</strong> apparent Hydrogen Index. This makes the<br />
MRILab service approach superior to traditional reservoir<br />
fluid sample processing that involves transferring samples<br />
uphole at the wellsite for conventional laboratory analysis.<br />
These measurements are significant for completion <strong>and</strong><br />
reservoir engineering as well as for reservoir underst<strong>and</strong>ing,<br />
<strong>and</strong> they are available at the wellsite immediately where they<br />
will have the most value.<br />
Features<br />
Identifies connate oil vs. oil-based mud filtrate<br />
differentiation<br />
Provides accurate fluid data for MRIL® log<br />
interpretation either wireline or LWD<br />
Measures hydrocarbon viscosity in-situ<br />
Complements MRIL logging service <strong>and</strong> extends the<br />
application of MRI technology in reservoir fluids<br />
determination<br />
Can be conveyed on wireline or drillpipe<br />
Measures the magnetic resonance properties of reservoir<br />
fluids as the RDT pumps from the reservoir into the<br />
borehole or sample chamber<br />
Measures T1 of fluid in the flowline while pumping with<br />
the RDT<br />
Measures T2 <strong>and</strong> diffusivity of stagnant fluid in the<br />
flowline<br />
MRILab® service is a modular component to the RDT reservoir<br />
description tool, providing real-time fluid analysis while pumping<br />
out to determine optimal time to obtain the cleanest samples<br />
possible.<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-31
Available immediately at vastly reduced cost compared to<br />
conventional laboratory measurement. Surface<br />
laboratory PVT analysis is both expensive <strong>and</strong> can take<br />
weeks or months to produce results. The actual task of<br />
collecting a reasonably uncontaminated reservoir fluid<br />
sample can require significant rig time. And during that<br />
time the clock is running on the well operators' <strong>and</strong><br />
other contractors' time, rental equipment, <strong>and</strong> personnel<br />
costs. It is not uncommon for physical drillstem tests for<br />
viscosity <strong>and</strong> other key fluid properties to cost the<br />
operator hundreds of thous<strong>and</strong>s of dollars when all the<br />
expenses are calculated<br />
More accurate measurements of native oil than other<br />
methods. Since the MRILab® measurements occur<br />
downhole on in-place <strong>and</strong> unaltered reservoir fluids,<br />
there is no direct human manipulation <strong>and</strong> no<br />
opportunity for the errors that can occur in surface lab<br />
work. The well operator can have confidence in the<br />
viscosity oil characterization measurement results on the<br />
native oil in place in the reservoir<br />
Results are available in real-time at the rigsite or by<br />
remote viewing. Viscosity <strong>and</strong> oil characterization are<br />
important attributes usable for making completion<br />
decisions<br />
Producing this information right away at the rigsite<br />
makes MRILab data infinitely more valuable than surface<br />
lab data that may be delayed for over a month. Similarly,<br />
the MRILab tool is equipped with real-time telemetry<br />
capability that makes the results of the measurements<br />
viewable remotely over a secure connection between<br />
client <strong>and</strong> the tool<br />
Health, Safety, <strong>and</strong> Environmental<br />
The ability to analyze the filtrate contamination level of<br />
reservoir fluids in real-time allows one to minimize the<br />
volume of fluid that is pumped from the formation into the<br />
wellbore before securing the fluid into the sample chamber.<br />
Further, real-time analysis of the reservoir fluids may reduce<br />
the number of samples that are required, thus eliminating<br />
the need for transfer <strong>and</strong> transport of hazardous fluid<br />
samples.<br />
Length<br />
ft (m)<br />
14<br />
(4.3)<br />
MRILab ® Service Specifications<br />
Diameter<br />
in. (mm)<br />
4.75<br />
(120.7)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
FluidXpert fluid analysis service – Real-time NMR fluid analysis from<br />
the MRILab® service while pumping out to determine optimal time to<br />
obtain sample. Available while pumping: real-time contamination<br />
estimation, fluid type probability, T 1 spectra, Hydrogen Index,<br />
capacitance, pressures, temperature, <strong>and</strong> pump rate. Available in<br />
real time at the wellsite <strong>and</strong> in a customer's office via InSite Anywhere®<br />
service.<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
400<br />
(181.4)<br />
3-32 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
Borehole Geophysics<br />
Wellbore Seismic<br />
High Resolution Seismic Imaging—(Near Offset VSP,<br />
Fixed Offset VSP, Walkaways, 3D VSP, Salt Proximity<br />
Surveys, Microseismic Surveys)<br />
<strong>Halliburton</strong> provides high-resolution images in the vicinity<br />
of the borehole using a number of different techniques<br />
depending on the objectives <strong>and</strong> the geologic environment.<br />
The techniques include vertical incidence vertical seismic<br />
profiles (VIVSP) in deviated wells, salt proximity surveys,<br />
tomographic velocity analysis, fixed offset VSP surveys<br />
(FOVSP), 2D walkaway surveys, 3D VSP, <strong>and</strong> ExactFrac® or<br />
microseismic surveys.<br />
<strong>Halliburton</strong> is an industry leader in providing advanced<br />
source <strong>and</strong> downhole array technologies for borehole<br />
seismic. <strong>Halliburton</strong>’s expertise serves to benefit operators<br />
with reduced rig time <strong>and</strong> improved data quality. Advanced<br />
source <strong>and</strong> receiver technology is crucial towards obtaining a<br />
more accurate <strong>and</strong> comprehensive geological picture of your<br />
well, field, or reservoir.<br />
<strong>Halliburton</strong> can offer custom built solutions for client’s<br />
seismic imaging field needs. For survey planning, we use the<br />
most advanced 3D wavefront modeling software available,<br />
GeoTomo’s VECON software.<br />
Multi-component arrays can be mobilized downhole to more<br />
accurately record true amplitude information of both<br />
compressional <strong>and</strong> shear waves.<br />
Compressional <strong>and</strong> shear images can be used in conjunction<br />
for lithology <strong>and</strong> fluid identification. Surveys can be repeated<br />
for time-lapse 4D views of fluid movements.<br />
Downhole seismic tools can also be used to passively listen to<br />
the reservoir <strong>and</strong> to map fluid movements, fault reactivation,<br />
or active fracture monitoring.<br />
A full array of tools is available for analyzing high resolution<br />
seismic data for reservoir imaging. <strong>Halliburton</strong> offers<br />
advanced pre-processing, including multi-component<br />
wavefield separation <strong>and</strong> final imaging using pre-stack depth<br />
migration (PSDM).<br />
High Resolution Seismic Imaging Features<br />
Generation of high-resolution multiple free images<br />
Mapping of steep structures (such as salt flanks)<br />
Detailed velocity cubes in areas of laterally changing<br />
velocity (shallow gas, permafrost, salt, etc.)<br />
Map structure, stratigraphy, lithology, <strong>and</strong> fluids with<br />
higher resolution <strong>and</strong> confidence than can be obtained<br />
with surface seismic<br />
Improve a poor data quality area or overcome no-data<br />
areas<br />
High Resolution Seismic Imaging Applications<br />
Profiling salt dome flanks<br />
Detecting natural fractures<br />
Enhanced seismic velocity analysis<br />
Primary seismic reflector identification<br />
Porosity <strong>and</strong> permeability estimation<br />
Anisotropy determination<br />
AVO analysis<br />
Determine height, length, <strong>and</strong> width of well frac or<br />
stimulation process<br />
Associated Answer <strong>Products</strong><br />
Vertical incidence VSP<br />
Synthetic seismogram<br />
FWS full wave sonic processing<br />
ExactFrac® services<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-33
Reservoir Geophysics<br />
Long Array Multi-Component Acquisition Tools<br />
<strong>Halliburton</strong> offers survey planning, data acquisition, <strong>and</strong><br />
data processing using multi-component long seismic arrays.<br />
Each tool combines advanced-source technology with<br />
industry leading multi-component <strong>and</strong> anisotropic<br />
migration software for a complete package of advanced<br />
custom designed reservoir imaging systems. Systems include<br />
the GeoChain VSP downhole receiver array.<br />
GeoChain VSP Downhole Receiver Array<br />
The GeoChain vertical seismic profile (VSP) array is<br />
designed for large borehole imaging surveys <strong>and</strong> can be used<br />
in open <strong>and</strong> cased holes with st<strong>and</strong>ard seven-conductor cable<br />
even in deep <strong>and</strong> hostile environments.<br />
GeoChain VSP Receiver Array Features<br />
Based on the proven ASR-1 downhole geophone<br />
Can be used in wells up to 25,000 psi <strong>and</strong> with hole sizes<br />
from 3.5-in. to 22-in.<br />
Unique ACS active cooling system allows continuous<br />
operation up to 356°F (180°C)<br />
Up to 42 satellites can be used in the array with a<br />
maximum tool spacing of 200 ft<br />
All satellite locking arms open <strong>and</strong> close simultaneously,<br />
<strong>and</strong> the entire string can lock into a 9.625-in. well in only<br />
30 seconds<br />
Can be run in the following configurations:<br />
No. of Tools Sample Rate<br />
5 1/2 ms<br />
10 1 ms<br />
21 2 ms<br />
26 2.5 ms<br />
32 3 ms<br />
42 4 ms<br />
Associated Answer <strong>Products</strong><br />
3D VSP imaging<br />
2D VSP imaging<br />
Interwell imaging<br />
ExactFrac® (microseismic) services<br />
Synthetic Seismic <strong>and</strong> Sonic Log Calibration<br />
The synthetic seismogram obtains an accurate tie between<br />
well logs measured in depth <strong>and</strong> the surface seismic image<br />
measured in two-way time. Correlation between logs <strong>and</strong><br />
seismic is important to verify interpreted horizons <strong>and</strong> to<br />
help determine the true phase of the surface seismic<br />
(important for advanced lithologic <strong>and</strong> fluid interpretations<br />
from seismic data).<br />
An accurate synthetic depends on sonic log calibration using<br />
data from a vertical seismic profile (VSP) or check shot<br />
survey. This calibration is necessary for a number of reasons<br />
such as:<br />
Sonic log <strong>and</strong> surface seismic are measured at different<br />
frequencies (dispersion)<br />
Sonic log <strong>and</strong> surface seismic can measure different rock<br />
<strong>and</strong> fluid volumes (fluid differences, invaded zones,<br />
damaged borehole, non-vertical ray paths, etc.)<br />
Calibration of the sonic log includes an analysis of the data to<br />
determine the cause of the differences (drift) between the<br />
sonic <strong>and</strong> the check shots.<br />
Depending on the cause of the drift, different methods of<br />
correction are used. The corrected sonic log is converted to<br />
interval velocity. Acoustic impedance is calculated using the<br />
corrected velocity log <strong>and</strong> the bulk density. Changes in<br />
acoustic impedance are used to create a reflection coefficient<br />
log, which is subsequently convolved with a desired wavelet<br />
to create a synthetic seismic trace.<br />
Recording of a shear sonic log or calculation of a synthetic<br />
shear log allows calculation of a 2D synthetic to analyze or<br />
predict AVO effects on the surface seismic. Perturbation of<br />
the rock parameters also allows study of the effects of fluid<br />
<strong>and</strong> lithology changes on the seismic character.<br />
Synthetic Seismic Features<br />
Helps promote accurate tie between well logs <strong>and</strong> surface<br />
seismic including phase determination<br />
Allows identification of multiples on the surface seismic<br />
Allows study of fluid <strong>and</strong> lithology effects on the seismic<br />
character<br />
Associated Answer <strong>Products</strong><br />
Vertical incidence VSP<br />
High resolution seismic imaging (walkaway, fixed offset,<br />
3D VSP, salt proximity, AVO Studies)<br />
FWS full wave sonic processing<br />
3-34 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
Vertical Incidence Vertical Seismic Profiling (VIVSP) Analysis<br />
The VIVSP analysis is a downhole seismic survey with the<br />
surface source positioned vertically above the geophones<br />
anchored in the well. In a vertical well, it is known as a zero<br />
offset VSP (ZOVSP) with the source positioned in a single<br />
location near the wellhead. In highly deviated wells, the<br />
source is moved along with the downhole geophone tool to<br />
keep the source vertically positioned above the geophone<br />
tool at each level.<br />
VIVSP analysis is useful for facilitating more accurate timedepth<br />
correlation between your well logs <strong>and</strong> your surface<br />
seismic. It is also useful for determining the phase of your<br />
surface seismic <strong>and</strong> for identifying multiples.<br />
VIVSP data provides an indispensable bridge between sonic<br />
log data <strong>and</strong> surface seismic data. In areas where it is difficult<br />
to obtain a good tie between the synthetic <strong>and</strong> the surface<br />
seismic, the VIVSP can be helpful to identify <strong>and</strong> resolve the<br />
differences.<br />
VIVSP is also very useful for predicting lithology, fluids, <strong>and</strong><br />
pore pressure ahead of the bit. Velocity trends that are useful<br />
for predicting pore pressure are calibrated at the well.<br />
VIVSP data is typically higher frequency than the surface<br />
seismic <strong>and</strong> can be used to better underst<strong>and</strong> the reflectivity<br />
seen in the surface seismic.<br />
VIVSP data can be useful for computing the dip of the<br />
reflecting horizons in the vicinity of the borehole.<br />
This can be used to confirm dips seen on dipmeter tools <strong>and</strong><br />
help project these dips away from the well.<br />
In deviated wells, the VIVSP also delivers a high resolution<br />
2D image beneath the wellbore. This image is typically<br />
higher frequency than the surface seismic, multiple free, <strong>and</strong><br />
tied directly to the wellbore in depth.<br />
<strong>Halliburton</strong> uses advanced proprietary software to h<strong>and</strong>le<br />
VSPs in the most dem<strong>and</strong>ing geologic environments<br />
(advanced editing, multi-component wavefield separation,<br />
interpolation, deconvolution, <strong>and</strong> migration tools).<br />
VSP software <strong>and</strong> processing can be used in the field, in a<br />
computing center linked to the wellsite, or in the client<br />
offices for special projects.<br />
VSP acquisition teams utilize customized energy sources <strong>and</strong><br />
the most advanced seismic tools available to record high-<br />
quality seismic data. The rugged, computerized logging<br />
systems precisely position the geophone tool in the well,<br />
properly synchronize the energy sources, <strong>and</strong> accurately<br />
transfer the measured data to the surface. The data obtained<br />
from VSPs provide extremely important information for<br />
enhancing <strong>and</strong> supplementing surface seismic data.<br />
VIVSP Features<br />
Allows detailed analysis of the downgoing <strong>and</strong> upgoing<br />
wavefield<br />
Real seismic trace rather than synthetic for log seismic<br />
correlation<br />
Provides detailed velocity analysis<br />
VSP Applications<br />
Direct correlation between surface seismic data <strong>and</strong> logs<br />
recorded in depth<br />
Calibrate wireline sonic data for correlating synthetic<br />
seismograms with conventional seismograms<br />
Mapping geologic structure in the vicinity of the wellbore<br />
Predict stratigraphy, lithology, <strong>and</strong> structure ahead of the<br />
drill bit to help save drilling time <strong>and</strong> costs<br />
Improve poor data-quality area or overcome no-data area<br />
Helps profile salt dome flanks<br />
Helps detect natural fractures<br />
Aids seismic identification of lithology<br />
Prospect delineation<br />
Enhanced seismic velocity analysis<br />
Primary seismic reflector identification<br />
Analyze multiple patterns<br />
Deconvolution operator for surface seismic data<br />
processing<br />
Porosity <strong>and</strong> permeability estimation<br />
2D <strong>and</strong> 3D stratigraphic <strong>and</strong> structural imaging<br />
Helps locate overthrust granite/sediment interface<br />
AVO analysis<br />
Associated Answer <strong>Products</strong><br />
Synthetic seismogram<br />
High resolution seismic imaging (walkaway, fixed offset,<br />
ocean bottom cable, salt proximity, AVO studies)<br />
FWS full wave sonic processing<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-35
ExactFrac ® <strong>Services</strong><br />
<strong>Halliburton</strong> eases frac modeling concerns by taking a fullservice<br />
approach to logging, offering both dipole sonic <strong>and</strong><br />
borehole seismic services. To give engineers the answers they<br />
require, our microseismic techniques provide real-time<br />
assessments of fracturing processes using two wells:<br />
A stimulation well where actual frac jobs are under way<br />
A monitor well equipped with a downhole geophone<br />
tool array with multiple sensors<br />
These microseismic techniques provide accurate information<br />
on the length, height, <strong>and</strong> distance of the frac being<br />
generated in the formation <strong>and</strong> can dramatically optimize<br />
the placement of future wells.<br />
ExactFrac <strong>Services</strong> Features<br />
Allows operators to optimize drilling program in field<br />
Improves later frac jobs (only zone you need to frac)<br />
Minimizes uncertainty in your fracturing program<br />
3-36 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
Sampling<br />
RDT Reservoir Description Tool<br />
RDT reservoir description tool is a modular, combinable<br />
formation tester <strong>and</strong> fluid-sampling tool. The RDT tool<br />
provides accurate pressure measurements. High-quality<br />
clean <strong>and</strong> representative formation fluid samples are<br />
collected, along with a broad range of valuable reservoir data.<br />
This is accomplished through:<br />
Pressure-gradient testing<br />
Permeability anisotropy testing<br />
Formation fluid properties monitoring<br />
Zero Shock pressure/volume/temperature (PVT)<br />
sampling<br />
The RDT Zero Shock PVT sampling method eliminates<br />
unanticipated fluid expansion <strong>and</strong> pressure shocks during<br />
pumping <strong>and</strong> sampling through its advanced digital control<br />
feedback system, which maintains a constant flowrate<br />
throughout the sampling process. Two closely spaced probes<br />
are st<strong>and</strong>ard, providing redundant packer seals <strong>and</strong> probes.<br />
In-situ PVT bubblepoint testing is performed while pumping<br />
to determine the ideal sampling pressure for oil-bearing<br />
reservoirs. Sample chambers are filled against hydrostatic<br />
pressure <strong>and</strong> additional pump pressure can be applied to<br />
maintain the sample in the single-phase condition while<br />
retrieving reservoir fluid to surface.<br />
Bubblepoint, compressibility, density, <strong>and</strong> resistivity are fluid<br />
properties which are monitored while pumping. In addition,<br />
spherical mobility, horizontal mobility, <strong>and</strong> anisotropy are<br />
monitored. When the MRILab® section is added, additional<br />
fluid properties including Hydrogen Index (HI), T 1 <strong>and</strong> T 2<br />
distributions, log mean T 1 , viscosity index, <strong>and</strong> capacitance<br />
are also monitored. Because these properties are monitored<br />
real-time, operators are able to identify the optimum point at<br />
which to divert fluid flow <strong>and</strong> collect samples.<br />
Applications<br />
Identify depleted <strong>and</strong> overpressured zones<br />
Assess reservoir fluid types <strong>and</strong> contacts<br />
Collect uncontaminated, representative, PVT-quality<br />
reservoir fluid samples<br />
Determine reservoir fluid PVT behavior<br />
Determine formation permeability <strong>and</strong> anisotropy<br />
Assess reservoir compartmentalization<br />
Verify reservoir isolation<br />
Detect interwell communication<br />
Quantify field-wide pressure trends<br />
Features<br />
The 100 cc pre-test chamber allows for rate- or pressurecontrolled<br />
fluid entry to ensure accurate bubblepoint<br />
<strong>and</strong> PVT analyses. The large volume chamber also allows<br />
multiple pretests per pad set without releasing the pad<br />
from the borehole wall<br />
Dual probe configuration provides improved horizontal<br />
<strong>and</strong> vertical permeability estimates due to probe<br />
proximity<br />
Determine real-time horizontal <strong>and</strong> vertical mobilities<br />
while sampling or pre-testing<br />
Dual probe configuration provides high reliability <strong>and</strong><br />
redundancy with multiple quartz <strong>and</strong> strain gauge<br />
pressure measurements<br />
Fluid type identification <strong>and</strong> contamination monitoring<br />
is used to discriminate between filtrate <strong>and</strong> formation<br />
fluid <strong>and</strong> to determine the optimal time to collect a fluid<br />
sample. Each multichamber section includes three<br />
1,000 cc PVT sample chambers<br />
Multiple fluid property sensor outputs are combined to<br />
yield reliable hydrocarbon/fluid typing even in oil- or<br />
synthetic-based mud<br />
Powerful pump reduces cleanup time, contamination<br />
level, <strong>and</strong> saves rig time<br />
Three flow control pump-out sections, configured for<br />
4,000; 6,000; <strong>and</strong> 8,000 psi pump pressure provide<br />
extended range pressure sampling capabilities in highly<br />
depleted or overbalanced conditions<br />
Zero Shock flowrate control ensures sample integrity<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-37
Pressure Testing <strong>and</strong><br />
Zero Shock Sampling<br />
DPS<br />
QGS<br />
FPS<br />
MCS<br />
MRILab<br />
MCS<br />
Low Mobility <strong>and</strong> Laminated<br />
Pressure Testing <strong>and</strong><br />
Zero Shock Sampling<br />
OPS<br />
QGS<br />
FPS<br />
MCS<br />
MRILab<br />
MCS<br />
Mini-DST <strong>and</strong> VIT<br />
Pressure Testing <strong>and</strong><br />
Zero Shock Sampling<br />
3-38 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
OPS<br />
DPS<br />
QGS<br />
QGS<br />
FPS<br />
MCS<br />
MRILab<br />
MCS<br />
Mini-DST <strong>and</strong> VIT<br />
Pressure Testing <strong>and</strong><br />
Zero Shock Sampling with<br />
Straddle Packer<br />
DPS<br />
QGS<br />
SPS<br />
FPS<br />
MCS<br />
MRILab<br />
MCS
DPS Dual Probe Section<br />
The DPS section deploys two independent probe/pad<br />
assemblies against the borehole wall for pressure drawdown/<br />
buildup analysis <strong>and</strong> pumping formation fluid. The DPS is<br />
designed to detect horizontal mobility (k h/μ), permeability<br />
(k h), <strong>and</strong> anisotropy (k v/k h) over an extended range of<br />
operation. The DPS pressure testing flowrate is precisely<br />
controlled with the advanced digital control feedback system,<br />
thus achieving steady-state pressure quickly <strong>and</strong> reducing<br />
required testing time. By running two dual probe sections in<br />
t<strong>and</strong>em, the RDT tool is used determine the pressure<br />
between the probes <strong>and</strong> profile permeability <strong>and</strong> anisotropy.<br />
This further enables an extended depth of investigation <strong>and</strong><br />
detection of permeability barriers.<br />
Features<br />
Design redundancy – two flow paths<br />
Operational efficiency<br />
Different pad configurations<br />
Closely spaced – enhanced permeability<br />
Probe shut-in valve – reduced flowline storage volume<br />
Faster buildup times – tight zones<br />
Resistivity fluid ID sensor<br />
Drawdown rate control 0.1 to 15 cc/sec<br />
Drawdown volume control 0.1 to100 cc<br />
Oval Pad<br />
Carbonate rocks, thinly bedded s<strong>and</strong>s, <strong>and</strong> naturally<br />
fractured reservoirs can exhibit a very challenging logging<br />
environment when pressure testing <strong>and</strong> fluid sampling are<br />
required. The challenge is due to, at least, reservoir<br />
heterogeneity <strong>and</strong> the difficulty of sealing the probes in these<br />
reservoirs. The RDT utilizes a proprietary oval pad section<br />
(OPS) to help overcome all of these challenges. The oval pad<br />
spans a 9-in. vertical section of the borehole, giving it the<br />
sealing advantages of a straddle packer but still maintaining<br />
the operational flexibility of a probe. In particular, the oval<br />
pad design ensures an effective seal for the probe during<br />
formation testing <strong>and</strong> fluid sampling in the presence of<br />
vuggy <strong>and</strong>/or fractured carbonate rocks. In addition to the<br />
increased vertical sealing area, the oval shape can reduce the<br />
sampling time due to a focusing effect the pad has on near-<br />
wellbore flow. Simulations show that when the complete<br />
testing system performance is considered, the oval pad<br />
reduces pumping times compared to a st<strong>and</strong>ard probe <strong>and</strong> in<br />
some cases a straddle packer.<br />
Straddle Packer<br />
The straddle packer section (SPS) offers advantages over<br />
probes in low permeability applications as well as<br />
heterogeneous environments. SPS incorporates a dual port<br />
design which offers unique benefits in non-horizontal wells<br />
when a density contrast exists between the drilling mud<br />
contaminant <strong>and</strong> reservoir fluids. The lighter fluid segregates<br />
towards the top of the packed-off interval. After initially<br />
pumping through both inlet ports <strong>and</strong> detecting reservoir<br />
fluid, one available option is to close the bottom port to flow<br />
only the lighter fluid through the top probe. Proper<br />
manipulation of the dual ports <strong>and</strong> taking advantage of<br />
naturally occurring fluid segregation of the fluids contained<br />
in the packed-off interval provides cleaner samples faster<br />
than samples attainable with only a single port tool. In<br />
carbonates, thinly bedded s<strong>and</strong>s, <strong>and</strong> naturally fractured<br />
reservoirs, most of the production occurs from small<br />
features. Such features make sampling <strong>and</strong> reservoir<br />
characterization difficult with a probe. The probe is more<br />
likely to be placed in a location that is characteristic of the<br />
rock matrix, which usually results in a tight test. The SPS<br />
isolates a 1 m interval, which is normally ample to<br />
characterize heterogeneous rock. The primary advantage of<br />
an SPS is its ability to cover a vertical interval where a probe<br />
is a pinpoint evaluation by comparison.<br />
FPS Flow-Control Pump-Out Section Features<br />
High pump rates-less contamination<br />
Faster pump-out times-reduced rig time<br />
Pump up or down (four-way valve)<br />
Multiple pump capability <strong>and</strong> flexible location in string<br />
Sampling flowrate – real-time control<br />
Outlet gauge controls sample filling<br />
Interchangeable pump pistons enable 4,000; 6,000; or<br />
8,000 psi pumps<br />
Instantaneous control (0.004 to 1.1 gpm)<br />
Flowrate feedback control<br />
Single phase samples<br />
QGS Quartz Gauge Section<br />
The quartz pressure transducer features 14.7 - 20,000 psi<br />
calibration at 350°F. Resolution is 0.02 psi with accuracy to<br />
± [1 psi + 0.01% reading].<br />
This sensor is just 0.75-in. OD × 2.25-in. long. Other<br />
properties include a low mass, which means shorter time to<br />
thermal stability <strong>and</strong> fast temperature compensation.<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-39
MRILab ® Section<br />
The MRILab® section measures in-situ reservoir fluid<br />
relaxation time at true reservoir conditions. The measured<br />
T 1, T 2, <strong>and</strong> the self-diffusion coefficient (D) of the reservoir<br />
fluids tie directly into important fluid characteristics such as<br />
viscosity index, fluid type, <strong>and</strong> contamination cleanup<br />
during pump-out.<br />
MCS Multi Chamber Section<br />
The MCS contains motorized chamber valves with three<br />
1,000 cc sample chambers. The chambers are detachable,<br />
transportable, <strong>and</strong> approved by the US department of<br />
transportation (DOT) <strong>and</strong> national association of corrosion<br />
engineers (NACE). Single phase nitrogen-charged sample<br />
chambers are available. Nitrogen-charged sample chambers<br />
maintain the fluid sample at higher pressure than st<strong>and</strong>ard<br />
chambers while the fluid is cooled <strong>and</strong> retrieved to the<br />
surface. Nitrogen charged sample volume is approximately<br />
550 cc at surface conditions.<br />
Module<br />
CVS<br />
QGS<br />
DPS<br />
OPS<br />
HPS<br />
FPS<br />
MCS<br />
PTS<br />
MRILab ®<br />
SPS<br />
Length<br />
ft (m)<br />
2.3<br />
(0.7)<br />
4.2<br />
(1.3)<br />
10.6<br />
(3.2)<br />
Slim Probe<br />
10.6<br />
6-in. Pad<br />
8.8<br />
(2.7)<br />
12.0<br />
(3.7)<br />
8.9<br />
(2.7)<br />
7.0<br />
(2.1)<br />
14.0<br />
(4.3)<br />
18.6<br />
(5.7)<br />
Diameter<br />
in. (mm)<br />
4.75<br />
(120.7)<br />
4.75<br />
(120.7)<br />
Sampling Tools Specifications<br />
Minimum<br />
Hole Size<br />
in. (mm)<br />
6<br />
(152.4)<br />
6<br />
(152.4)<br />
4.75<br />
(120.7) 6<br />
5.0 @ Probe (152.4)<br />
(127)<br />
4.75<br />
(120.7) 6<br />
5.6 @ Pad (152.4)<br />
(142.2)<br />
4.75<br />
(120.7)<br />
4.75<br />
(120.7)<br />
4.75<br />
(120.7)<br />
4.75<br />
(120.7)<br />
4.75<br />
(120.7)<br />
4.75<br />
(120.7)<br />
6<br />
(152.4)<br />
6<br />
(152.4)<br />
6<br />
(152.4)<br />
6<br />
(152.4)<br />
6<br />
(152.4)<br />
6<br />
(152.4)<br />
CVS Chamber Valve Section<br />
The CVS contains motorized sample chamber shut-in valves,<br />
an expulsion valve, <strong>and</strong> a check valve which prevents<br />
backflush. The MCS carries up to two st<strong>and</strong>ard 2-3/4 gallon<br />
SFTT sample chambers typically used for large volume,<br />
non-PVT, water sampling.<br />
Associated Answer <strong>Products</strong><br />
PTA pressure transient analysis<br />
In-situ real-time bubble point<br />
Advanced analysis from Applied Formation Evaluation<br />
Centers<br />
Maximum<br />
Hole Size<br />
in. (mm)<br />
18<br />
(457.2)<br />
18<br />
(457.2)<br />
18<br />
(457.2)<br />
17.5<br />
(444.5)<br />
18<br />
(457.2)<br />
18<br />
(457.2)<br />
18<br />
(457.2)<br />
18<br />
(457.2)<br />
18<br />
(457.2)<br />
12.25<br />
(311.1)<br />
Maximum<br />
Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
17,000<br />
(117.2)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
3-40 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
75<br />
(34.0)<br />
350<br />
(176.7) 102<br />
400<br />
(46.3)<br />
(204.4)<br />
350<br />
(176.7)<br />
350<br />
(176.7)<br />
350<br />
(176.7)<br />
350<br />
(176.7)<br />
350<br />
(176.7)<br />
350<br />
(176.7)<br />
350<br />
(176.7<br />
350<br />
(176.7)<br />
385<br />
(174.6)<br />
385<br />
(174.6)<br />
296<br />
(134.3)<br />
450<br />
(204.1)<br />
290<br />
(131.5)<br />
211<br />
(95.7)<br />
450<br />
(204.1)<br />
858<br />
(389.2)
SFT-IV Sequential Formation Tester IV Tool<br />
The SFT-IV sequential formation tester IV tool is used for<br />
gathering the quality formation data required to evaluate<br />
reservoir potential <strong>and</strong> plan well completions <strong>and</strong> is part of<br />
our comprehensive line of wireline formation testing<br />
services. This service includes a full suite of open-hole test<br />
tools designed to allow the best possible test in any formation<br />
under any condition.<br />
Features<br />
Surface controlled pre-test volumes (0 to 20 cc)<br />
Multiple drawdown without pad resetting<br />
Variable rate drawdown (0.1 to 0.33 cc/sec)<br />
Backflushing of pre-test volume (0 to 20 cc)<br />
Variable hydraulic pad seating pressure<br />
Optional precision quartz gauge (14.7 to 12,000 ±1.0 psi<br />
accuracy)<br />
All parameters necessary for a successful test—accuracy,<br />
adaptability, speed, <strong>and</strong> reliability—are designed into the<br />
test tool<br />
Pre-test does not start until the operator gives the<br />
comm<strong>and</strong>, allowing:<br />
– Verification of padset before starting pre-test<br />
– Evaluation of mudcake properties from padset<br />
data<br />
Proprietary quartz transducer technology allows better<br />
response to pressure changes<br />
Length 1<br />
ft (m)<br />
17.8<br />
(5.4)<br />
Temperature compensation crystal, attached to the<br />
pressure crystal, provides improved temperature<br />
compensation <strong>and</strong> pressure measurement accuracy<br />
Crystal size <strong>and</strong> special construction features permit<br />
reliable transducer operation—even under harsh<br />
borehole conditions<br />
The SFT-IV probe section is articulated to ensure that pad seals in<br />
deviated holes or washed out sections. It features surface selectable<br />
pretest volumes <strong>and</strong> up to three sample chambers.<br />
SFT-IV Sequential Formation Tester IV Tool Specifications<br />
Diameter 2<br />
in. (mm)<br />
5.5<br />
(139.7)<br />
Maximum Pressure<br />
psi (Mpa)<br />
12,000<br />
(82.7)<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-41<br />
HAL9152<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
Varies<br />
1 Without sample chambers.<br />
2 St<strong>and</strong>ard configuration.<br />
Various chamber configurations are available for specific applications or formation conditions. Check with your local<br />
<strong>Halliburton</strong> representative for further information. The 2.75 gal (10.4 L) chambers are H 2 S compatible.
SFTT Sequential Formation Test Tool<br />
The SFTT sequential formation test tool measures wellbore<br />
<strong>and</strong> formation fluid pressure at any point in the well with a<br />
petroquartz pressure transducer. The SFTT tool can also<br />
collect representative formation fluid samples for up to two<br />
test depths in one trip into the well.<br />
The following measurements are available for monitoring<br />
<strong>and</strong> recording at the surface system:<br />
Hydrostatic (mud column) <strong>and</strong> formation pressures<br />
Continuous recording of time so significant events<br />
during the test can be timed for computations<br />
Pre-test volumes<br />
Petroquartz pressures<br />
Petroquartz pressure sample rate<br />
Petroquartz transducer temperature<br />
Features<br />
Variable pre-test volumes (5 to 10 cc)<br />
Drawdown rates (0.5 to 2 cc/sec)<br />
Drawdown after padset established<br />
Adaptable to H2S St<strong>and</strong>ard precision quartz gauge<br />
Determine reservoir pressure<br />
Identify gas <strong>and</strong> oil reservoir boundaries<br />
Monitor reservoir intercommunication<br />
Indicate areas of pressure depletion<br />
Estimate formation permeability by pressure/time curve<br />
correlation<br />
Determine chemical concentrations <strong>and</strong> reservoir fluid<br />
properties through laboratory analysis of retrieved<br />
formation samples<br />
Measure flow <strong>and</strong> shut-in pressures vs. time<br />
Tool Length<br />
ft (m)<br />
SFTT-B<br />
SFTT-C<br />
The SFTT tool features ruggedized construction for measuring precise<br />
formation <strong>and</strong> wellbore-hydrostatic pressure readings. The SFTT tool can<br />
also collect reservoir fluid samples in two separate chambers for analysis<br />
of fluid properties with st<strong>and</strong>ard 2.75-gal chambers <strong>and</strong> optional 1.0, 5.0,<br />
<strong>and</strong> 8.0 gal chambers.<br />
The advanced <strong>Halliburton</strong> quartz gauge is st<strong>and</strong>ard <strong>and</strong> can measure<br />
pressures with an accuracy of ± (1.0 psi + 0.01% of the reading);<br />
resolution is 0.01 psi <strong>and</strong> a repeatability of 1.0 psi<br />
SFTT Sequential Formation Test Tool Specifications<br />
22.1<br />
(6.7)<br />
18.9<br />
(5.8)<br />
Diameter<br />
in. (mm)<br />
6.5<br />
(165.1)<br />
6.5<br />
(165.1)<br />
3-42 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL703<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
350<br />
(176.7)<br />
HAL9252<br />
Weight<br />
lb (kg)<br />
675<br />
(306.2)<br />
525<br />
(238.1)<br />
The sequential formation test tool is also available for hostile environments. For more information, reference<br />
the HSFT hostile sequential formation tester tool on page 55.
RSCT Rotary Sidewall Coring Tool<br />
The RSCT tool diamond-drills cores perpendicular to the<br />
borehole wall with continuous monitoring of the coring<br />
process. After gamma ray depth positioning, a backup shoe is<br />
extended to decentralize <strong>and</strong> hold the tool securely against<br />
the formation. A diamond bit rotating at 2,000 rpm cuts a<br />
0.9375-in. OD, 1.75-in. long sample from the formation.<br />
Surface control of weight-on-bit optimizes drilling.<br />
After the sample has been cut, a slight vertical movement of<br />
the bit breaks the core sample from the formation. The bit<br />
containing the sample is then withdrawn into the tool <strong>and</strong><br />
the core is punched into a receiver tube. An indicator reveals<br />
both the existence <strong>and</strong> length of the sample. The tool is then<br />
ready for the next selected core point.<br />
The RSCT tool is used to obtain core samples in consolidated<br />
formations. A tubular shaped drill bit with diamond cutting<br />
edges is used to drill the core. The core is recovered as a<br />
cylindrical shaped plug of the formation.<br />
The system operates independently from other systems on<br />
the logging truck or skid. The only input required is a source<br />
of AC voltage. A recording device is necessary for recording<br />
gamma ray correlation data.<br />
The downhole tool is controlled from the surface by use of<br />
the control panel.<br />
Applications<br />
Rotary core samples collected by the RSCT tool can be used<br />
to provide:<br />
More accurate readings of porosity <strong>and</strong> permeability that<br />
reduce reservoir analysis variables. Microfractures in<br />
core samples taken with percussion tools cause false<br />
readings of porosity <strong>and</strong> permeability<br />
Information useful in fine-tuning MRIL® data<br />
Reliable data for rock mechanical analysis necessary for<br />
hydraulic fracturing design, wellbore stability analysis,<br />
<strong>and</strong> s<strong>and</strong> potential prediction<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-43<br />
HAL9184<br />
HAL9183
Features<br />
Allows 30 or more cores to be taken in one run<br />
Can be run on Toolpusher service or coiled tubing to<br />
acquire cores in deviated, extended reach, <strong>and</strong> horizontal<br />
wells<br />
A core length indicator takes the guesswork out of core<br />
recovery<br />
St<strong>and</strong>-alone tools can be run on third-party logging<br />
units<br />
Originally designed to recover cores in hard rock<br />
formations inaccessible with percussion tools, the<br />
RSCT tool can be used with equal success in soft<br />
rock formations<br />
Length<br />
ft (m)<br />
18.1<br />
(5.5)<br />
RSCT Rotary Sidewall Coring Tool Specifications<br />
Diameter<br />
in. (mm)<br />
4.87<br />
(123.7)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Gamma ray tool positioning provides accurate core<br />
point location<br />
Core samples are undistorted with consistent cylindrical<br />
geometry which allows a wide range of petrophysical<br />
testing <strong>and</strong> analysis<br />
Allows for evaluation of pre-existing formation damage<br />
by providing core samples free of distortions caused by<br />
percussion tools<br />
HRSCT hostile rotary sidewall coring tool available for<br />
use in hostile environments<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
275<br />
(124.7)<br />
3-44 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
SWC Side Wall Coring Tool<br />
The SWC side wall coring tool allows geologists to take a<br />
sample of a prospective formation traversed by the borehole.<br />
These sidewall core samples can improve log analysis, help to<br />
identify a rock's type <strong>and</strong> origin, <strong>and</strong> can be used to<br />
determine the exact location of gas <strong>and</strong> oil, gas <strong>and</strong> water, or<br />
oil <strong>and</strong> water contacts within a reservoir. In some cases,<br />
sidewall cores can even discover productive reservoirs not<br />
evident on logs.<br />
The SWC tool consists of a propelling explosive material <strong>and</strong><br />
hollow core barrels housed in the body of the gun. The tool is<br />
lowered to a predetermined depth <strong>and</strong> fired, one shot at a<br />
time. The barrels containing the core samples are then<br />
retrieved by means of a cable attaching the barrels to the gun.<br />
The SWC tool utilizes a single cable running through <strong>and</strong> in-<br />
between the barrel back <strong>and</strong> barrel. The two ends of the cable<br />
are secured to the side rails of the gun, helping to reduce the<br />
number of broken cables. In addition, release rings adapted<br />
to the top of the barrel control entry depth <strong>and</strong> velocity <strong>and</strong><br />
provide flexibility during the coring process.<br />
Applications<br />
Clay typing<br />
Fluid saturation estimation<br />
Length<br />
ft (m)<br />
7.7<br />
(2.4)<br />
SWC Side Wall Coring Tool Specifications<br />
Diameter<br />
in. (mm)<br />
4.5<br />
(114.3)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Matrix makeup<br />
Grain size <strong>and</strong> cementing agents<br />
Paleonthological data<br />
API oil gravity<br />
Gas <strong>and</strong> oil presence<br />
Porosity <strong>and</strong> permeability estimations can also be made<br />
using sidewall core analysis. However, these estimates should<br />
never be used to extensively evaluate porosity or permeability<br />
since there is a high probability that the core structure has<br />
been altered by the impact of the core barrel into the<br />
formation.<br />
Features<br />
Area specific – can shoot 24 to 144 cores on a single trip<br />
into the well<br />
Depth correlation via gamma ray or SP application<br />
Sampling can be done at any time before casing is run<br />
Allows sampling of very soft formations<br />
Permits positive verification of formation type indicated<br />
by the other open-hole logs<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
400<br />
(204.4)<br />
Weight<br />
lb (kg)<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-45<br />
215<br />
(97.5)
HRSCT Hostile Rotary Side Wall Coring Tool<br />
The HRSCT hostile rotary sidewall coring tool provides a<br />
new approach for acquiring multiple sidewall core samples<br />
from an earth formation <strong>and</strong> special means for storing <strong>and</strong><br />
identifying individual samples in multiple tubes for wireline<br />
operation. This apparatus is specifically designed with high<br />
efficiency to provide high-speed bit rotation combined with<br />
high torque for best drilling performance.<br />
The coring tool apparatus consist of control/power<br />
electronics <strong>and</strong> includes a hydraulic valve section, motor<br />
drive section, <strong>and</strong> the m<strong>and</strong>rel section. The descriptions of<br />
each section are as follows.<br />
Hydraulic Valve Section<br />
This section incorporates multiple solenoid valves for<br />
independent control of the tool functions such as, setting<br />
tool, tilting bit box, bit rotation, drilling/bit advance control,<br />
<strong>and</strong> core storage. The main feature of this section is the bit<br />
advance control mechanism which is based on applying bit<br />
weight <strong>and</strong> receiving positive feedback from the bit torque<br />
for the active control system. Small incremental increase <strong>and</strong><br />
decrease in bit weight are possible to provide for smooth<br />
drilling without the risk of bit stalling.<br />
Motor Drive Section<br />
This section consists of an electric motor with a small pump<br />
at one end, for providing hydraulic pressure for all the<br />
auxiliary functions. The other end of the motor is connected<br />
to a clutch mechanism used for engaging <strong>and</strong> disengaging the<br />
bit on dem<strong>and</strong>. The output of the clutch is directly coupled<br />
to the bit box through a flexible steel drive shaft. The main<br />
feature of this drive system is that by eliminating the<br />
hydraulic pumps <strong>and</strong> motors, high drive train efficiencies of<br />
as much as 80% is possible without sacrificing performance.<br />
The clutch mechanism can also be adjusted to slip at the<br />
torque rating of the electric motor to eliminate motor/bit<br />
stalling while drilling.<br />
Maximum<br />
Temperature °F<br />
M<strong>and</strong>rel Section<br />
This section incorporates a bit box movable by actuators for<br />
tilting, advance/retract, bit break, <strong>and</strong> storage functions. The<br />
bit box incorporates several sets of bevel <strong>and</strong> spur gears to<br />
translate the direction of the rotation of the flexible shaft into<br />
normal direction to the axis of the wellbore. Finally, multiple<br />
core separator tubes are positioned in a carousel manner. The<br />
carousel rotates on dem<strong>and</strong> from the hydraulic power section<br />
after depositing a core to place a washer for positive<br />
identification. The carousel stores up to sixty 2.12-in. cores<br />
that would otherwise be length prohibitive if a single tube is<br />
used. During the coring operation, the m<strong>and</strong>rel is secured to<br />
the borehole using two powerful backup pistons instead of a<br />
single backup arm. The backup pistons are sized so that<br />
minor slippage that could cause m<strong>and</strong>rel movement can be<br />
eliminated. This reduces the possibility of lodging <strong>and</strong><br />
sticking the bit in the formation.<br />
Features<br />
High temperature AC motor drives the bit for:<br />
– Full power across entire temperature range<br />
– Minimum post-job re-fit time<br />
Software control offers “cruise control” option<br />
Surplus power:<br />
– 1500 rpm with 22-in.-lb torque for fast drill times<br />
Excellent coring capacity:<br />
– 60 cores 2.12-in. L × 1.0 diameter<br />
Fail-safe retract includes bit-box <strong>and</strong> backup pistons<br />
Combinable<br />
Sensor coring record includes:<br />
– ROP, bit torque, <strong>and</strong> RPMs<br />
–Drilled core length<br />
–Recovered core length<br />
Pressure<br />
HRSCT Hostile Rotary Side Wall Coring Tool Specifications<br />
Maximum<br />
Pressure<br />
psi<br />
Push Pull<br />
Tension<br />
lb<br />
Push Pull<br />
Compression lb<br />
40 20,000 100,000 50,000<br />
Maximum OD<br />
in.<br />
4.75 nominal 5.125<br />
at st<strong>and</strong>offs<br />
3-46 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
Length<br />
ft<br />
Minimum / Maximum<br />
Hole<br />
in.<br />
30 6.25 - 12
Hostile—Slimhole Formation Evaluation<br />
HEAT Hostile Environment Applications Tool Suite<br />
The HEAT hostile environment applications tools suite<br />
comprises six logging instruments—a cablehead-tension<br />
load cell <strong>and</strong> associated centralizer, decentralizer, flex-joint,<br />
<strong>and</strong> telemetry assemblies. Each HEAT tool contains an<br />
internal temperature sensor that provides quality control<br />
data related to operational characteristics <strong>and</strong> tool<br />
electronics. Such information is usually critical only in very<br />
hot well conditions—in particular, when temperatures over a<br />
prolonged period are near the 500°F limit of the toolstring.<br />
The following are tools in the HEAT suite:<br />
HDIL Hostile Dual Induction Log (see page 5)<br />
HEDL Hostile Environment Dual Laterolog<br />
HFWS Hostile Full Wave Sonic Tool<br />
HSDL Hostile Spectral Density Tool<br />
HDSN Hostile Dual-Spaced Neutron Tool<br />
HNGR Hostile Natural Gamma Ray Tool<br />
HSFT Hostile Slim Formation Tester Tool<br />
Features<br />
HEAT suite tools are digital <strong>and</strong> smaller than st<strong>and</strong>ard<br />
logging tools—2.75-in. to 3.5-in. OD for HEAT suite<br />
versus 3.625-in. to 4.5-in. OD for st<strong>and</strong>ard tools<br />
The HEAT sonic, neutron, <strong>and</strong> gamma ray tools can all<br />
operate in open <strong>and</strong> cased holes<br />
Built to h<strong>and</strong>le the severe conditions encountered in<br />
deep <strong>and</strong> hot hydrocarbon-bearing formations<br />
Can be combined in almost any configuration to suit the<br />
borehole geometry <strong>and</strong> formation evaluation<br />
requirements of each job<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-47
HEDL Hostile Environment Dual Laterolog Tool<br />
The HEDL hostile environment dual laterolog tool is a<br />
wireline-deployed formation resistivity device designed for<br />
extreme borehole temperatures <strong>and</strong> pressures. It is the tool of<br />
choice when those resistivities routinely exceed 100 ohm m,<br />
especially in highly conductive muds.<br />
The HEDL tool is combinable with other hostile<br />
environment tools, e.g. the density <strong>and</strong> neutron tools to<br />
permit simultaneous resistivity/porosity measurements in<br />
the reservoirs. The tool is designed to be run with the<br />
HETS hostile environment telemetry sub <strong>and</strong> must be<br />
located immediately below the HETS sub <strong>and</strong> a 2.75-in.<br />
diameter isolation sub. From top to bottom, the HEDL tool<br />
assembly consists of:<br />
A flasked electronic assembly<br />
An upper toroid sub<br />
An alpha sub<br />
A lower toroid sub<br />
Features<br />
2.75-in. diameter permits slimhole <strong>and</strong> through drillpipe<br />
logging of high-temperature/high-pressure wells<br />
Performs two resistivity/porosity measurements: a deep<br />
laterolog (LLd) <strong>and</strong> a shallow laterolog (LLs) resistivity<br />
measurement<br />
Calibrated using three external resistor networks that<br />
simulate relatively low, medium, <strong>and</strong> high resistivities<br />
Under conditions of high Rt <strong>and</strong> low Rm <strong>and</strong> at<br />
temperatures higher than 350°F, the HEDL tool provides<br />
the basic formation resistivity data to aid formation<br />
evaluation<br />
Typical HEDL log recorded in highly resistive carbonate formations<br />
HEDL Hostile Environment Dual Laterolog Tool Specifications<br />
Length<br />
ft (m)<br />
21<br />
(6.4)<br />
Diameter<br />
in. (mm)<br />
2.75<br />
(69.9)<br />
3-48 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL9137<br />
Maximum Pressure<br />
psi (Mpa)<br />
25,000<br />
(172.4)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
450<br />
(232.2)<br />
Weight<br />
lb (kg)<br />
300<br />
(136.1)
HFWS Hostile Full Wave Sonic Tool<br />
The HFWS hostile full wave sonic tool is a 2.75-in. acoustic<br />
velocity logging tool that is a part of the HEAT suite hostile<br />
environment applications tool toolstring. The HFWS tool,<br />
along with all of the HEAT suite sensors, have a pressure<br />
rating of 25,000 psi (172 400 kPa). The HEAT suite logging<br />
tools are designed for continuous operation of six hours at<br />
500°F (260°C).<br />
The HFWS tool, like the larger in diameter (3.625-in.)<br />
FWS full wave sonic tool, provides compressional wave,<br />
refracted shear wave, <strong>and</strong> Stoneley wave properties of<br />
downhole formations for a wide range of petrophysical,<br />
geological, <strong>and</strong> geophysical applications. To minimize the<br />
number of logging trips required for complete formation<br />
evaluation, the HFWS tool is compatible with all HEAT suite<br />
logging toolstrings. A liquid filled borehole is required for<br />
sonic logging, <strong>and</strong> can be used in fresh, salt, or oil-based<br />
mud systems.<br />
The HFWS tool can be compared to having two sonic tools<br />
within the same toolstring—a long-spaced sonic tool for<br />
traditional full waveform open-hole sonic logging, <strong>and</strong><br />
located within the transmitter-to-receiver offset, a cement<br />
bond tool that utilizes the second transmitter <strong>and</strong> two<br />
receivers. The upper transmitter <strong>and</strong> the lower four receivers<br />
array are utilized for FWS full wave sonic logging. The lower<br />
(second) transmitter <strong>and</strong> the upper two receivers are utilized<br />
for cement bond logging <strong>and</strong> short, offset compressional<br />
wave travel time. The long transmitter to-receiver offset<br />
allows for the acquisition of borehole sonic data beyond the<br />
effects of any near-wellbore altered region. The long offset<br />
also allows for the acquisition of high-quality sonic data in<br />
enlarged boreholes where critical angle effects would affect<br />
sonic tools with short transmitter-to-receiver offsets.<br />
Applications<br />
Full waveform open-hole sonic logging<br />
Cement bond logging<br />
Acquisition of borehole sonic data<br />
The natural gamma ray, X-X caliper, Y-Y caliper, P-wave travel time<br />
<strong>and</strong> P-wave semblance quality are presented in Track 1. The monopole<br />
waveform data is presented in Track 2 in the MicroSeismogram<br />
format (X-Z) <strong>and</strong> in an X-Y waveform presentation in Track 3.<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-49<br />
HAL9171
Features<br />
Advanced system design <strong>and</strong> software processing with<br />
long transmitter-to-receiver offsets <strong>and</strong> 1/2 ft receiver-toreceiver<br />
spacings<br />
Detection of signals at all receivers for each transmitter<br />
pulse to promote constant source characteristics<br />
Automatic gain control of each receiver helps preserve<br />
signal amplitude<br />
Downhole digitizing helps eliminate transmission noise<br />
<strong>and</strong> allows broadb<strong>and</strong> frequency response<br />
Low-frequency response allows detection of low<br />
frequency Stoneley waves <strong>and</strong> multiple Δt measurements<br />
per depth interval<br />
Facilitates continuous uninterrupted recording of full<br />
waveform signals<br />
Ability to record various types of information including<br />
tool data, quality curves, <strong>and</strong> final results<br />
Operator-selectable multiple modes of tool operation,<br />
digitally recorded waveform data, <strong>and</strong> improved porosity<br />
estimates using both Δtc <strong>and</strong> Δts Facilitates lithology identification by means of velocity<br />
ratio, Δts /Δtc , <strong>and</strong> location of gas zones, even in poor<br />
hole conditions <strong>and</strong> cased holes<br />
Indication of permeability variations with depth from<br />
Stoneley wave attenuation <strong>and</strong> Δt<br />
Detection of naturally fractured zones, determination of<br />
rock elastic constants, <strong>and</strong> estimation of formation<br />
strength <strong>and</strong> least horizontal stress<br />
Prediction of vertical extent of hydraulic fractures using<br />
the RockXpert2 analysis package<br />
Improved vertical resolution for detection of thinner<br />
beds (Beds as thin as 3-in. can be identified with the<br />
t curves)<br />
Time-to-depth correlation for seismic correlation<br />
Combining sonic slowness data with formation density<br />
data are the required input information for synthetic<br />
seismograms<br />
Length*<br />
ft (m)<br />
30.2<br />
(9.2)<br />
Gamma ray <strong>and</strong> caliper are presented in Track 1, compressional<br />
wave travel time (DTC) is presented in Track 4, <strong>and</strong> the P-wave<br />
semblance quality is presented in Track 3.<br />
HFWS Hostile Full Wave Sonic Tool Specifications<br />
Diameter<br />
in. (mm)<br />
2.75<br />
(69.9)<br />
*Add 3.50 ft (1.1 m) for each in-line centralizer (usually two).<br />
** 6 hour<br />
Maximum Pressure<br />
psi (Mpa)<br />
25,000<br />
(172.4)<br />
This is a hard rock example. Natural gamma ray, caliper, <strong>and</strong><br />
VpVs are presented in Track 1. The P-wave travel time <strong>and</strong> the<br />
refracted shear wave travel time are presented in Track 2. The<br />
semblance quality is presented in an image format in Track 3 for<br />
the P-wave <strong>and</strong> refracted shear wave.<br />
3-50 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL9172<br />
HAL9173<br />
Maximum Temperature**<br />
°F (°C)<br />
500<br />
(260)<br />
Weight<br />
lb (kg)<br />
340<br />
(154.2)
HSDL Hostile Spectral Density Log<br />
The HSDL hostile spectral density log is a section of the<br />
HEAT suite system. It is available with the source-detector<br />
pad either as a bottom-only in-line configuration (2.75-in.<br />
tool OD) or as a powered, extendable configuration (3.5-in.<br />
tool OD). It is fully combinable with all other HEAT suite<br />
tools.<br />
The HSDL log measures formation density, photoelectric<br />
factor (a lithology indicator), <strong>and</strong> borehole diameter. It<br />
measures formation density by emitting gamma rays into the<br />
formation <strong>and</strong> recording the energy of gamma rays reflected<br />
by the formation to the two detectors in the tool. The HSDL<br />
log measures borehole diameter with a spring-loaded caliper<br />
arm that opens <strong>and</strong> closes as the tool is pulled through<br />
changes in hole diameter.<br />
Additionally, as for all <strong>Halliburton</strong>’s HEAT suite services, the<br />
HSDL log provides reliable data in temperatures up to 500°F<br />
<strong>and</strong> pressures as high as 25,000 psi that are encountered in<br />
hot hydrocarbon bearing formations.<br />
Applications<br />
Determination of formation porosity<br />
Identification of formation lithology regardless of<br />
formation fluid type<br />
Indication of gas when used in combination with a<br />
neutron log<br />
Features<br />
More precise delineation of thinly bedded formations<br />
using the unfiltered Pe curve<br />
Curves indicating data quality are displayed on a<br />
computer screen in real-time <strong>and</strong> recorded on the log<br />
Advanced correction algorithm is applied to density data<br />
in real-time<br />
Rigid tungsten pad incorporates a 1.5-curie cesium-137<br />
source <strong>and</strong> two high-efficiency scintillation detectors<br />
designed to maintain high gamma counts<br />
Rugged construction <strong>and</strong> advanced gain stabilization<br />
help maintain measurement integrity under varying<br />
temperature conditions<br />
Combinable with a complete family of tools that<br />
operates under the DITS digital interface telemetry<br />
system<br />
Extensively characterized in test pits with a full set of<br />
correction charts available<br />
2.75-in. OD for use in slimholes makes it possible to<br />
design a through-formation evaluation program for<br />
holes as small as 3.5-in.<br />
Uses a new 4D technique to account for the density <strong>and</strong><br />
photoelectric absorption of the formation <strong>and</strong> mudcake<br />
without assuming any correlation between these<br />
variables. Besides yielding a superior density, these<br />
calculations provide information for compensating the<br />
Pe measurement <strong>and</strong> computing useful quality indicators<br />
such as the two component density correction<br />
Typical Field Output of the HSDL Log<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-51<br />
HAL846
Associated Answer <strong>Products</strong><br />
The wellsite answer product is formation density <strong>and</strong> Pe<br />
Density data is also used with open-hole sensors as input<br />
to <strong>Halliburton</strong>’s mineralogy, open-hole, <strong>and</strong> cased-hole<br />
saturation analysis to provide a complete formation<br />
evaluation product. These include:<br />
Equipment Length<br />
ft (m)<br />
In-Line Pad<br />
Extendable Pad<br />
– ULTRA multi-mineral evaluation program<br />
– CORAL complex lithology analysis<br />
–LARA laminated reservoir analysis<br />
– SASHA shaly s<strong>and</strong> analysis<br />
HSDL Hostile Spectral Density Log Specifications<br />
13.8*<br />
(4.2)<br />
23.8<br />
(7.3)<br />
*Usually run with the HPDC-A—if so add 3.8 ft (1.2 m)<br />
**6 hour<br />
Diameter (minimum)<br />
in. (mm)<br />
2.75<br />
(69.9)<br />
3.50<br />
(89.9)<br />
Maximum Pressure<br />
psi (Mpa)<br />
25,000<br />
(172.4)<br />
25,000<br />
(172.4)<br />
Maximum<br />
Temperature**<br />
°F (°C)<br />
500<br />
(260)<br />
500<br />
(260)<br />
Weight<br />
lb (kg)<br />
176<br />
(79.8)<br />
456<br />
(206.8)<br />
3-52 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
HDSN Hostile Dual-Spaced Neutron Tool<br />
The HDSN hostile dual-spaced neutron tool is a section of<br />
the HEAT suite system. The HDSN tool consists of<br />
combinable, high-quality, small-diameter tools capable of<br />
comprehensive formation evaluation in harsh environments.<br />
Applications<br />
Provides a neutron porosity log, i.e. the porosity of the<br />
formation as indicated by the detection of neutron<br />
radiation induced in the formation by the tool<br />
Investigates formation lithology, using a steady state,<br />
neutron-generating source of radioactive americiumberyllium<br />
(AmBe) <strong>and</strong> two thermal neutron detectors.<br />
Neutrons emitted from the source are slowed <strong>and</strong><br />
scattered by the surrounding media, <strong>and</strong> the resulting<br />
neutron field is sampled at two locations. The neutron<br />
flux is converted to electrical signals for logging<br />
Features<br />
Can be deployed in both open <strong>and</strong> cased-hole wells<br />
Commonly run with the powered decentralizer to<br />
provide HDSN tool eccentering <strong>and</strong> to furnish a<br />
continuous st<strong>and</strong>off measurement that helps improve<br />
porosity calculations, especially over rugose intervals<br />
Uses caliper data from the decentralizer to correct<br />
porosity for hole size<br />
Extensively characterized in test pits with a full set of<br />
correction charts available<br />
Temperature <strong>and</strong> pressure ratings of 500°F (for 6 hours)<br />
<strong>and</strong> 25,000 psi, respectively to h<strong>and</strong>le severe conditions<br />
encountered in deep <strong>and</strong> hot hydrocarbon-bearing<br />
formations<br />
Specially designed He3 detectors minimize the effects of<br />
elevated temperature on observed count rates <strong>and</strong><br />
computed porosity<br />
2.75-in. OD for use in slimholes<br />
Small OD to design a through formation evaluation<br />
program for holes as small as 3.5 in.<br />
Combinable in almost any configuration to suit borehole<br />
geometry <strong>and</strong> provide appropriate formation evaluation<br />
information<br />
Typical Field Output of the HDSN Tool<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-53<br />
HAL846
Associated Answer <strong>Products</strong><br />
The wellsite answer product is the neutron porosity<br />
NPHI<br />
Neutron porosity data is also used with other open-hole<br />
sensors as input to <strong>Halliburton</strong>’s mineralogy, open-hole,<br />
<strong>and</strong> cased-hole saturation analysis to provide a complete<br />
formation evaluation product. These include:<br />
Length*<br />
ft (m)<br />
15.3<br />
(4.6)<br />
– ULTRA multi-mineral evaluation program<br />
– CORAL complex lithology analysis<br />
–LARA laminated reservoir analysis<br />
– SASHA shaly s<strong>and</strong> analysis<br />
HDSN Hostile Dual-Spaced Neutron Tool Specifications<br />
Diameter<br />
in. (mm)<br />
2.75<br />
(69.9)<br />
Maximum Pressure<br />
psi (Mpa)<br />
25,000<br />
(172.4)<br />
Maximum<br />
Temperature**<br />
°F (°C)<br />
Weight<br />
lb (kg)<br />
3-54 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
500<br />
(260)<br />
*The length <strong>and</strong> weight include the HGNI instrument section, which is required to run the HDSN tool. Add 7.04 ft<br />
(2.1 m) when run with the in-line, bowspring decentralizer.<br />
**6 hour<br />
179<br />
(81)
HNGR Hostile Natural Gamma Ray Tool<br />
The HNGR hostile natural gamma ray tool is a section of<br />
the HEAT suite system. Along with the HGNI tool, the<br />
HNGR tool can be run alone or with any other hostile service<br />
in either an open or cased-hole.<br />
The HNGR tool is used to record naturally occurring gamma<br />
radiation. Gamma ray measurements are used for geologic<br />
correlation, depth control, <strong>and</strong> computing shale <strong>and</strong> clay<br />
volumes. Shale volume data can then be applied to correct<br />
the apparent porosities indicated by the acoustic, neutron,<br />
<strong>and</strong> density logs.<br />
When wellbore conditions are not favorable for a definitive<br />
SP response, a gamma ray curve is recorded in its place.<br />
Applications<br />
Record natural gamma radiation<br />
Features<br />
Commonly run with the powered decentralizer to press<br />
the toolstring along the borehole wall <strong>and</strong> to furnish a<br />
continuous st<strong>and</strong>off measurement<br />
Temperature <strong>and</strong> pressure ratings of 500°F (for 6 hours)<br />
<strong>and</strong> 25,000 psi, respectively to h<strong>and</strong>le severe conditions<br />
encountered in deep <strong>and</strong> hot hydrocarbon-bearing<br />
formations<br />
2.75-in. OD for use in slimholes makes it possible to<br />
design through-formation evaluation programs for holes<br />
as small as 3.5-in.<br />
Combinable in almost any configuration to suit borehole<br />
geometry <strong>and</strong> provide appropriate formation evaluation<br />
information calibration <strong>and</strong> wellsite checks<br />
Curves indicating data quality are displayed on a<br />
computer screen in real-time <strong>and</strong> recorded on the log<br />
Length*<br />
ft (m)<br />
11.6<br />
(3.5)<br />
Typical Field Output of the HNGR Tool<br />
HNGR Hostile Natural Gamma Ray Tool Specifications<br />
Diameter<br />
in. (mm)<br />
2.75<br />
(69.9)<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-55<br />
HAL846<br />
Maximum Pressure<br />
psi (Mpa)<br />
25,000<br />
(172.4)<br />
Maximum Temperature**<br />
°F (°C)<br />
500<br />
(260)<br />
*The length <strong>and</strong> weight include the HGNI instrument section, which is required to run the HNGR tool.<br />
**6 hour<br />
Weight*<br />
lb (kg)<br />
146<br />
(66.2)
HSFT Hostile Sequential Formation Tester Tool<br />
The 3.125-in. OD HSFT tool is capable of formation<br />
testing in conditions where conventional tools cannot. The<br />
HSFT tool can be run in holes as slim as 4-in. <strong>and</strong> at<br />
temperatures <strong>and</strong> pressures up to 400°F <strong>and</strong> 25,000 psi.<br />
The HSFT tool can take an unlimited number of pressure<br />
tests <strong>and</strong> up to two fluid samples per trip in the well.<br />
Formation pressures are determined using a high resolution,<br />
high temperature quartz gauge.<br />
The HSFT tool is fully combinable with the HEAT suite<br />
toolstring, allowing open-hole data acquisition <strong>and</strong><br />
formation testing in the same trip in the well.<br />
Features<br />
Maximum tool OD 3-1/8 in. tool design includes selfcontained<br />
st<strong>and</strong>offs, reducing the contact area between<br />
the tool <strong>and</strong> the borehole wall <strong>and</strong> minimizing the<br />
chance of differential sticking, especially in difficult hole<br />
conditions <strong>and</strong> depleted reservoirs<br />
Designed for wellbore diameters as small as 4 in.<br />
With optional backup shoe, pad can extend to 12.25 in.<br />
Sampling flowrate controlled by air or fluid cushions<br />
Two 1-gal sample chambers available<br />
Tool, reinforced pad design, <strong>and</strong> quartz gauge proven<br />
reliable to 400°F<br />
Backup strain gauge provides redundancy<br />
Low flowline volume reduces storage resulting in faster<br />
pressure tests in low mobility reservoirs, often<br />
encountered in high-pressure, high-temperature<br />
(HPHT) wells<br />
Self-cleaning s<strong>and</strong> screen design prevents snorkel<br />
plugging<br />
Extends pressure <strong>and</strong> temperature range over<br />
conventional testers<br />
Combinable with HEAT suite resistivity, sonic, <strong>and</strong><br />
porosity logs to increase rig time savings<br />
Low power consumption electronics reduces internal<br />
heat generation <strong>and</strong> extends tool operating time<br />
Length*<br />
ft (m)<br />
28.0<br />
(8.5)<br />
4000<br />
Legend<br />
3000<br />
Pressure Used<br />
Pressure Data<br />
2000<br />
Hydro Static 1<br />
Draw Down<br />
Fill Up<br />
1000<br />
Stop<br />
Hydro Static 2<br />
0 HAL9144<br />
ETIM (sec)<br />
Real-time plot of HSFT tool data provides test monitoring <strong>and</strong> a<br />
drawdown mobility estimate.<br />
Real-time HSFT tool analysis plot identifies flow regime <strong>and</strong> aids<br />
operator in determining when to terminate test, resulting in saved rig<br />
time.<br />
Time (sec): T(-1.5)<br />
Buildup analysis performed on HSFT tool data<br />
3-56 Open-Hole <strong>Wireline</strong> <strong>Services</strong><br />
Pressure (psi)<br />
Pressure (psi) <strong>and</strong> Derivative<br />
Pressure (psi)<br />
6000<br />
5000<br />
1e+07<br />
1e+06<br />
1e+05<br />
10000<br />
0<br />
100<br />
Pressure/Time Depth: XX879 ft<br />
200<br />
300<br />
400<br />
HAL9139<br />
1000<br />
Legend<br />
Derivative Plot<br />
100<br />
Delta Pressure<br />
Match<br />
10<br />
1<br />
10<br />
100<br />
1000<br />
Buildup Time (sec)<br />
5000<br />
4980<br />
4960<br />
4940<br />
4920<br />
4900<br />
4880<br />
0<br />
500<br />
600<br />
700<br />
Spherical LogLog Depth: XX879 ft<br />
Spherical FasTest Depth: XX879 ft<br />
Legend<br />
Pressure Used<br />
Pressure Data<br />
P*Fast Curve Fit<br />
800<br />
5e-5 10e-5 15e-5 20e-5 25e-5 30e-5 35e-5 40e-5 45e-5 50e-5<br />
HSFT Hostile Sequential Formation Tester Tool Specifications<br />
Diameter<br />
in. (mm)<br />
3.125<br />
(79.4)<br />
Maximum Pressure<br />
psi (Mpa)<br />
25,000<br />
(172.4)<br />
Maximum Temperature<br />
°F (°C)<br />
400<br />
(204.4)<br />
Weight<br />
lb (kg)<br />
525<br />
(231.8)<br />
*HSFT tool only; does not include HPSU or sample chambers. Minimum toolstring length for pressures only, including gamma<br />
<strong>and</strong> telemetry sub 55 ft (16.8 m) HPSU length: 8.33 ft (2.5 m); weight 120 lb (54.4 kg); OD: 2.75 in. (69.9 mm).<br />
HAL11253
Auxiliary <strong>Services</strong><br />
Multi-Conductor LockJar ®* System<br />
The multi-conductor LockJar® system minimizes the risk of<br />
unproductive rig time in logging operations.<br />
The benefits of using wireline instruments to log oil <strong>and</strong> gas<br />
wells can diminish quickly if the logging string becomes<br />
stuck in the wellbore while tripping. Now, with multiconductor<br />
LockJar wireline technology available from<br />
<strong>Halliburton</strong>, that risk can be dramatically reduced.<br />
Unlike previous jars, the LockJar system arrives at the<br />
wellsite ready to run. Logging crews can be trained to use the<br />
tool in minutes, so a jar service technician is not required on<br />
location. There is even a hydraulic time delay that allows the<br />
crew to pull the toolstring through a tight spot without<br />
activating the tool.<br />
The new LockJar system can be adjusted right at the wellsite<br />
to begin metering the jar with a pull from the surface of 1,700<br />
to 4,000 lb. It can function reliably in reservoir temperatures<br />
up to 400°F <strong>and</strong> at pressures as high as 22,500 psi. However,<br />
those specifications can be easily increased because the tool is<br />
pressure balanced.<br />
Features<br />
Mechanical lock helps prevent inadvertent triggering<br />
during logging operations<br />
Hydraulic time delay allows actuation at any load above<br />
the mechanical lock setting <strong>and</strong> is not sensitive to<br />
pressure or temperature<br />
Balanced pressure increases the hydrostatic pressure<br />
rating by providing compensation to prevent collapsing<br />
Protected seal <strong>and</strong> impact surfaces enhance downhole<br />
reliability by minimizing friction from borehole fluids<br />
<strong>and</strong> problems associated with debris<br />
All internal parts, including the jar mechanism <strong>and</strong><br />
conductive path, are sealed <strong>and</strong> segregated from the<br />
wellbore<br />
Permits operators to free-fall wireline in regions where<br />
persistent sticking problems have dictated the need for<br />
drillpipe-conveyed logging operations<br />
System ready to run upon arrival<br />
*LockJar is a registered trademark of Evans Engineering, Inc.<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-57<br />
HAL14045
Operation<br />
In a typical open-hole logging string, the LockJar® system is<br />
placed immediately above the logging or formation testing<br />
tools. To augment the force with which the weight is thrown<br />
up hole after the jar is activated, it is mated with an enhancer.<br />
It has been demonstrated in the lab that the LockJar tool’s<br />
impulse is more than twice as powerful with up to five times<br />
more duration when the enhancer is added to the jar.<br />
The LockJar tool is usually run in the string in the following<br />
order from the cable head down: enhancer, cable mode <strong>and</strong><br />
telemetry sub-assemblies, <strong>and</strong> the jar. In combination, they<br />
Length<br />
ft (m)<br />
11.4<br />
(3.49**)<br />
Maximum OD<br />
in. (cm)<br />
3.625<br />
(9.20)<br />
create as large a mass as possible to help the jar release stuck<br />
logging tools. The enhancer stores energy in Belleville springs<br />
which propel the hammer into an anvil upon activation of<br />
the jar which generates the impact <strong>and</strong> impulse that are<br />
directed down towards the stuck point.<br />
Borehole Conditions<br />
Borehole fluids: salt, fresh, oil, <strong>and</strong> air<br />
Tool positioning: centralized eccentralized<br />
Multi-Conductor LockJar ® System Specifications<br />
Minimum Hole Size<br />
in. (cm)<br />
4.0<br />
(10.16)<br />
Maximum Hole Size<br />
in. (cm)<br />
N/A*<br />
*Tool not restricted on maximum hole size<br />
**Length of enhancer is 10.1 ft (3.07 m); combination jar <strong>and</strong> enhancer is 21.5 ft. (6.56 m).<br />
***Weight of the enhancer is 290 lb (131.5 kg).<br />
Maximum Pressure<br />
psi (Kpa)<br />
20,000<br />
(137 895)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
400<br />
(204)<br />
Weight<br />
lb (kg)<br />
365<br />
(165***)<br />
3-58 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
RWCH Releaseable <strong>Wireline</strong> Cable Head<br />
The RWCH tool has an electrically activated wireline<br />
release system as opposed to the tension activated release<br />
system of conventional cable heads. Tension activated heads<br />
require a safety factor to avoid premature release of the<br />
wireline. This safety factor keeps you from utilizing the full<br />
safe load on the wireline when trying to free stuck tools from<br />
the borehole. The RWCH tool allows you to utilize this extra<br />
tension to free stuck tools. This additional tension has proven<br />
very successful at freeing stuck tools <strong>and</strong> avoiding fishing<br />
operations. This extra pull also allows you to safely run heavy<br />
toolstrings in deep wells.<br />
The RWCH tool can reduce the costs of obtaining wireline<br />
logs in areas that are prone to tool sticking. It has reduced the<br />
incidence of fishing for stuck tools in problem areas, saving<br />
customers expensive <strong>and</strong> risky fishing jobs.<br />
Features<br />
Allows for greater pulling of stuck tools at any depth <strong>and</strong><br />
in any conditions<br />
Able to support heavy toolstrings by utilizing the full<br />
strength of the wireline, regardless of depth<br />
Electrically controlled release from the surface<br />
Contains a conventional 2.3125-in. fishing neck<br />
Includes a special sub designed to allow easy rigup <strong>and</strong><br />
rig-down<br />
Allows the maximum pull to be applied at any depth in<br />
the well regardless of the total depth if the backup weak<br />
point is not used<br />
Allows the release to be aborted as long as the fusible<br />
alloy has not reached melting temperature<br />
Length<br />
ft (m)<br />
6.3<br />
(1.9)<br />
RWCH Operation<br />
RWCH Releaseable <strong>Wireline</strong> Cable Head Specifications<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-59<br />
135<br />
(61.2)<br />
HAL9188
Toolpusher Logging (TPL) Service<br />
Today’s search for oil <strong>and</strong> gas is heavily influenced by the<br />
rapid growth of technology. New tools <strong>and</strong> equipment are<br />
being built, new production <strong>and</strong> recovery methods are being<br />
tested, <strong>and</strong> new exploration techniques are being developed.<br />
Drilling programs are becoming increasingly complex <strong>and</strong><br />
many wells now commonly include highly deviated or<br />
horizontal sections. In these cases, obtaining quality<br />
formation evaluation data with conventional wireline<br />
methods may be impossible or impractical at best—severely<br />
restricting the options available to the operator.<br />
The Toolpusher logging (TPL) service provides an<br />
innovative solution to this significant problem. TPL service<br />
utilizes drillpipe to effectively transport conventional electric<br />
wireline logging tools to the zone of interest. This method<br />
eliminates many of the problems associated with conveying<br />
tools through highly deviated or horizontal sections of the<br />
well. It also helps eliminate problems caused by:<br />
<strong>Wireline</strong> key seating<br />
Differential sticking of tools or wireline<br />
Swelling formations<br />
HAL607<br />
Toolpusher Drillpipe Conveyed Logging System<br />
Heavy muds<br />
Doglegs<br />
Cuttings bridging off the wellbore<br />
The TPL service has successfully logged thous<strong>and</strong>s of highly<br />
deviated <strong>and</strong> horizontal wells, including:<br />
Wells with temperatures over 400°F (204°C)<br />
Depths exceeding 24,000 ft (7315 m)<br />
Logged intervals over 10,000 ft (3048 m)<br />
The Toolpusher latch assembly has been deployed <strong>and</strong><br />
latched at angles of up to 97° with a maximum logged angle<br />
of over 104°. Average job time at 12,000 ft is 16 to 18 hours.<br />
Toolpusher service is designed to run both st<strong>and</strong>ard <strong>and</strong><br />
modified wireline logging tools. The quick change, attached<br />
to the top of the logging toolstring, is attached to the bottom<br />
of a connector sub. Then the connector sub is attached to the<br />
drillpipe. The connector sub, available in three diameters,<br />
has slots cut through it so circulation can be accomplished at<br />
any time during a logging operation.<br />
3-60 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
Toolpusher service requires a variety of specialty subs <strong>and</strong><br />
hardware. Among the subs are the downhole tension device,<br />
multiconductor swivel adapter, <strong>and</strong> offset, alignment, flex,<br />
knuckle, <strong>and</strong> pad locator subs. Some of the specialty<br />
hardware includes the rig floor display, spinning st<strong>and</strong>-offs,<br />
stiffening collars, hole finders, bullnoses, protective sleeves,<br />
<strong>and</strong> st<strong>and</strong>offs. The lists of equipment can get quite extensive.<br />
Each piece is utilized for special situations <strong>and</strong> the variety<br />
makes Toolpusher service a very versatile <strong>and</strong> adaptable<br />
system. Many toolstrings have unique hardware to assist in<br />
getting the best possible data.<br />
Toolpusher service was the first drillpipe conveyed logging<br />
system introduced in the field. It has a very long track record<br />
<strong>and</strong> has proven to be very reliable. Unlike our competitors,<br />
Toolpusher allows the customer to circulate at any time<br />
during the operation. The side-entry sub (SES) has a larger<br />
through-bore than the competition, which allows fishing<br />
operations to proceed as normal without restriction.<br />
Applications<br />
Conventional open-hole <strong>and</strong> cased-hole logging<br />
Formation testing <strong>and</strong> coring<br />
Vertical seismic profiling<br />
Ultrasonic <strong>and</strong> electrical imaging<br />
Cement <strong>and</strong> casing evaluation<br />
Features<br />
Control of pull off tension allows the operator to pull test<br />
to check the mechanical latch<br />
Tool Section<br />
Toolpusher Logging (TPL) Service Specifications<br />
Length<br />
ft (m)<br />
Diameter<br />
in. (mm)<br />
Side-Entry Sub SES * *<br />
Positive Latch/Unlatch Quick Change<br />
Assembly<br />
7-Conductor Pump Down Head **<br />
Multi Conductor Swivel Assembly<br />
DITS Downhole Tension Device<br />
DITS Single Knuckle Joint<br />
DITS Flex Joint<br />
DITS Double Knuckle Joint<br />
*<br />
3.02<br />
(0.9)<br />
3.78<br />
(1.2)<br />
3<br />
(0.9)<br />
5.64<br />
(1.7)<br />
5<br />
(1.5)<br />
3.625<br />
(92.1)<br />
2.0 or 2.25<br />
(50 or 57.1)<br />
3.625<br />
(92.1)<br />
3.625<br />
(92.1)<br />
3.625<br />
(92.1)<br />
3.625<br />
(92.1)<br />
3.625<br />
(92.1)<br />
*Size selection is based on casing size <strong>and</strong> drillpipe size <strong>and</strong> type.<br />
**Length <strong>and</strong> weight are variable depending upon the latching conditions.<br />
No metal around female electrical connection reduces<br />
the possibility of shorting<br />
Female wet connect is floating <strong>and</strong> spring loaded,<br />
eliminating the movement of the connection <strong>and</strong><br />
reducing noise<br />
New wiper gl<strong>and</strong>s to clean the male probe removes<br />
conductive films from the pin<br />
Multiple o-ring seal after the connection is made to<br />
effectively seal the connection<br />
Spring loaded sleeve protects downhole parts before<br />
latching<br />
Male probe completely covered after latching to help seal<br />
out invading fluids<br />
Employs conventional high-resolution wireline tools to<br />
provide formation data with quality equal to that of<br />
wireline-conveyed logs. Conventional rig tripping<br />
procedures are used to mechanically position logging<br />
tools in the zone of interest<br />
Formation data is available in real-time at the wellsite.<br />
Also, zones of interest can be relogged by lowering the<br />
blocks<br />
Rig up on the drillpipe rather than multiple runs with<br />
conventional wireline can save time. Prior planning with<br />
your <strong>Halliburton</strong> representative can determine which<br />
method is more economical<br />
Provides mud circulation throughout the operation.<br />
This reduces the risk of tools getting stuck <strong>and</strong><br />
minimizes further hole deterioration<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
Maximum Temperature<br />
°F (°C)<br />
400<br />
(204)<br />
400<br />
(204)<br />
400<br />
(204)<br />
400<br />
(204)<br />
350<br />
(176.7)<br />
400<br />
(204)<br />
400<br />
(204)<br />
400<br />
(204)<br />
Weight<br />
lb (kg)<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-61<br />
*<br />
*<br />
**<br />
70<br />
(31.8)<br />
96<br />
(43.5)<br />
50<br />
(22.7)<br />
140<br />
(63.5)<br />
75<br />
(34)
CTL Coiled Tubing Logging<br />
As the only major service company that designs,<br />
manufactures, <strong>and</strong> operates its own coiled tubing equipment,<br />
<strong>Halliburton</strong> incorporates important input from field<br />
personnel <strong>and</strong> customers into designing features that are<br />
strategically directed toward the most effective possible job<br />
performance. Deploying logging tools on coiled tubing is one<br />
of the more innovative uses of <strong>Halliburton</strong> coiled tubing.<br />
Installing logging cable inside the coiled tubing allows tools<br />
to be deployed into highly deviated wells <strong>and</strong> permits a<br />
variety of remedial functions.<br />
CTL logging differentiates itself from drillpipe conveyed<br />
logging by offering:<br />
Continuous circulation capabilities<br />
Pressure control while moving pipe<br />
Electrical connections made at the surface to eliminate<br />
wet latches<br />
Tolerance for high mud solids content<br />
Relogging of any interval, eliminating multiple latch<br />
runs<br />
Constant speed logging capability<br />
Applications<br />
Cement bond logging in highly deviated wells<br />
Production logging to determine water entry points in<br />
highly deviated wells<br />
Open-hole logging in deviated air-drilled wells that need<br />
pressure control<br />
Tool OD<br />
Coiled Tubing Size<br />
Top Connection<br />
Bottom Connection<br />
Coiled Tubing Cablehead Specifications<br />
1.50 in.<br />
(38.1 mm)<br />
1.00 to 1.50-in.<br />
(25.4 to 38.1 mm)<br />
Roll-on or<br />
OECO “A” Box<br />
1-3/16-in. (30.2 mm) 12 UN<br />
Type “A” Pin<br />
Single-trip underbalanced perforating with long<br />
gunstrings<br />
Setting plugs <strong>and</strong> packers in deviated wells with pinpoint<br />
depth control<br />
Features<br />
Purpose-built coiled tubing cableheads<br />
– Shear pin release<br />
– Flow-release<br />
High pressure surface termination assemblies<br />
– St<strong>and</strong>ard integral plumbing<br />
–DNV certified<br />
Self-contained unit, requires no rig<br />
Can continuously pump fluids into well while moving<br />
pipe<br />
L<strong>and</strong> or offshore system designs<br />
No workover rig required when using coiled tubing<br />
Reduced potential damage to formation<br />
Can be <strong>and</strong> is typically used on live wells (no kill fluids<br />
introduced into well)<br />
Acts as tool transport medium for deviated <strong>and</strong><br />
horizontal wells<br />
Advanced data acquisition system to monitor key job<br />
parameters on tubing management<br />
2.00 in.<br />
(50.8 mm)<br />
1.50-in. <strong>and</strong> above<br />
(38.1 mm <strong>and</strong> above)<br />
Roll-on or<br />
OECO “A” Box<br />
1-3/16-in. (30.2 mm) 12 UN<br />
Type “A” Pin or<br />
3-5/8-in. (92.1 mm) DITS Tool<br />
2.50 in.<br />
(63.5 mm)<br />
1.50-in. <strong>and</strong> above<br />
(38.1 mm <strong>and</strong> above)<br />
OECO “A” Box or<br />
AMMT Box<br />
1-3/16-in. (30.2 mm) 12 UN<br />
Type “A” Pin<br />
Fishing Neck Size 1.0-in. (25.4 mm) External 1.375-in. (34.9 mm) External 1.812-in. (46.0 mm) Internal<br />
Emergency Release Force Range<br />
Logging Cable<br />
3,200 to 10,000 lb<br />
(1,451.5 to 4,536 kg)<br />
7/32-in (5.6 mm) or<br />
5/16-in. (7.9 mm)<br />
monoconductor<br />
5,000 to 30,000 lb<br />
(2,268 to 13,608 kg)<br />
5/16-in. (7.9 mm)<br />
monoconductor or<br />
3/8-in. (9.5 mm),<br />
7/16-in. (11.1 mm),<br />
0.457-in. (11.6 mm), or<br />
15/32-in. (11.9 mm) multiconductor<br />
Flow-release in<br />
conjunction with shear pins<br />
7/32-in (5.6 mm) or<br />
5/16-in. (7.9 mm)<br />
monoconductor or<br />
3/8-in. (9.5 mm),<br />
7/16-in. (11.1 mm),<br />
0.457-in. (11.6 mm), or<br />
15/32-in. (11.9 mm) multiconductor<br />
3-62 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
BHPT Borehole Properties Tool<br />
The BHPT borehole properties tool is a DITS tools<br />
compatible electric logging tool, which provides signals used<br />
to determine characteristics of wellbore fluids. The primary<br />
outputs of a BHPT log are pressure, temperature, <strong>and</strong><br />
borehole fluid resistivity. This information has long been<br />
requested by our clients <strong>and</strong> now is available during the first<br />
logging pass in a newly drilled well.<br />
The BHPT tool is normally run in conjunction with other<br />
logging services but may also be used as a st<strong>and</strong>-alone<br />
logging tool requiring the use of a telemetry sub. Open-hole,<br />
cased-hole, <strong>and</strong> drillpipe conveyed logging environments<br />
will accommodate the BHPT tool <strong>and</strong> two external diameters<br />
are available. The open-hole version is st<strong>and</strong>ard 3.625-in.<br />
<strong>and</strong> a smaller 3.375-in. version may be necessary in heavy<br />
4.5-in. casing <strong>and</strong> slimhole applications.<br />
Downhole pressure <strong>and</strong> temperature readings can assist<br />
clients in blowout prevention, mud weight corrections,<br />
determining formation fracture pressures, thief-zone<br />
identification, determining wellbore fluid pressure gradients<br />
in deviated holes, thermal gradient calculation, bottomhole<br />
temperature, <strong>and</strong> detection of dynamic fluid environments<br />
within the wellbore, including location of gas entry points in<br />
air-drilled wells.<br />
The resistivity sensor provides accurate, real-time<br />
information about mud resistivity at any depth <strong>and</strong><br />
temperature in the wellbore. This information is required<br />
during water saturation calculations. The R m data may be<br />
used in invasion diameter calculations <strong>and</strong> also to identify<br />
abnormal induction <strong>and</strong> laterolog readings caused by<br />
borehole fluid effects. In cased-hole environments, the<br />
resistivity sensor can locate fluid levels <strong>and</strong> contact depth of<br />
static oil <strong>and</strong> water.<br />
Pre- <strong>and</strong> post-job maintenance requires flushing the pressure<br />
entry port to remove mud debris <strong>and</strong> create a pressure buffer<br />
to the sensor. Calibrations involve coefficient entry <strong>and</strong><br />
internal resistor network readings.<br />
The BHPT tool can be used at any location in the logging<br />
stack depending on the data acquisition depth priorities with<br />
the exception that it must be run below the telemetry sub.<br />
The BHPT tool is available in two diameter sizes: a 3.375-in.<br />
tool <strong>and</strong> a 3.625-in. tool. The 3.625-in. BHPT tool is used<br />
specifically in open-hole applications. The smaller diameter<br />
3.375-in. tool is used in cased-hole wells (with heavy 4.25-in.<br />
casing), <strong>and</strong> in slimhole applications.<br />
Typical Field Output of the BHPT Tool<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-63<br />
HAL9394
Features<br />
Outputs real-time pressure, temperature, <strong>and</strong> mud<br />
resistivity data in the case that no similar measurements<br />
are taken in the toolstring configuration<br />
Aids in blowout prevention<br />
Makes mud-weight corrections<br />
Determines formation fracture pressures<br />
Identifies thief zone<br />
Determines wellbore fluid-pressure gradients in deviated<br />
holes<br />
Determines thermal-gradient calculation<br />
Determines bottomhole temperature<br />
Detects dynamic fluid environments within the wellbore,<br />
which also includes locating gas entry points in airdrilled<br />
wells<br />
Length<br />
ft (m)<br />
5.02<br />
(1.5)<br />
5.02<br />
(1.5)<br />
The resistivity sensor provides accurate, real-time<br />
downhole temperature <strong>and</strong> mud resistivity information at<br />
any depth. This resistivity measurement can be used to:<br />
Make water saturation calculations<br />
Make invasion diameter calculations<br />
Identify abnormal induction <strong>and</strong> laterolog<br />
measurements (caused by borehole fluid effects)<br />
Locate fluid levels <strong>and</strong> contact depth of static oil <strong>and</strong><br />
water in cased-hole wells<br />
Associated Answer <strong>Products</strong><br />
Absolute pressure <strong>and</strong> differential pressure<br />
Absolute temperature <strong>and</strong> differential temperature<br />
Mud resistivity<br />
BHPT Borehole Properties Tool Specifications<br />
Diameter<br />
in. (mm)<br />
3.375<br />
(85.7)<br />
3.625<br />
(92.1)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
95<br />
(43.1)<br />
Cased-Hole<br />
107<br />
(48.5)<br />
Open-Hole<br />
3-64 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
FIAC Four Independent Arm Caliper Tool<br />
The FIAC four independent arm caliper tool is a four-arm<br />
caliper which provides information on the borehole<br />
geometry of the wellbore. Unlike other X-Y caliper services,<br />
the FIAC tool has four independent caliper measurements.<br />
The FIAC tool, run as a separate or combined service,<br />
provides an accurate measurement of the borehole diameter<br />
in four orthogonal directions with respect to the tool body.<br />
This survey is useful in calculating cement volume, selecting<br />
packer seats for formation sampling, <strong>and</strong> identifying <strong>and</strong><br />
locating washouts <strong>and</strong> bridges in the borehole, as well as<br />
identify borehole ovality.<br />
Borehole size may range from 3.625-in. diameter to 22-in.<br />
diameter. The caliper arms are mounted at 90° angles to each<br />
other <strong>and</strong> provide a continuous X-Y (borehole axis is Z)<br />
borehole measurement. This tool is combinable with any<br />
other DITS st<strong>and</strong>ard tools.<br />
When the FIAC tool is combined with the SDDT<br />
navigation package, the borehole geometry information is<br />
oriented with respect to both magnetic north <strong>and</strong> the highside<br />
of the wellbore. The borehole azimuth, borehole<br />
deviation, <strong>and</strong> relative bearing of the X <strong>and</strong> Y caliper data are<br />
presented in a continuous log presentation. This allows the<br />
correlation of the borehole geometry with the drilling<br />
process, such as correlation of the long axis of the borehole to<br />
the high-side/low-side of the well. The FIAC tool differs from<br />
the competition by providing four independent caliper<br />
measurements, whereas with types of other four arm<br />
calipers, the X-X <strong>and</strong> Y-Y arms are paired together to provide<br />
only two diameter measurements.<br />
A borehole geometry presentation is created by combining the FIAC<br />
<strong>and</strong> SDDT data. Orientation data from the SDDT navigation tool is<br />
presented in Track 1, the deviation <strong>and</strong> hole azimuth are presented as<br />
text values every 50 ft <strong>and</strong> as continuous curves. The averaged X <strong>and</strong> Y<br />
calipers are presented in the depth track. The two independent X-X<br />
calipers are presented in Track 2 along with a bit size data. The two<br />
independent Y-Y calipers are presented in Track 3 along with the bit size<br />
data. This presentation illustrates an oval borehole with the long axis of<br />
the borehole aligned with the high-side/low-side of the deviated well.<br />
The short axis of the borehole is smaller than bit size, indicating the<br />
presence of mudcake.<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-65<br />
HAL9189
Features<br />
Four independent caliper measurements to provide<br />
needed borehole geometry data<br />
Combined with a navigation package the borehole<br />
geometry profile can be oriented with respect to<br />
magnetic north as well as to the high side of deviated or<br />
horizontal wells<br />
Borehole geometry information can be used to monitor<br />
hole size <strong>and</strong> shape with wellbore deviation <strong>and</strong> azimuth<br />
for basic geo-mechanical analysis<br />
Length<br />
ft (m)<br />
13.9<br />
(4.2)<br />
Helps optimize drilling <strong>and</strong> mud systems by the<br />
evaluation of borehole geometry along with mud weight<br />
<strong>and</strong> type, bit type, <strong>and</strong> ROP<br />
More accurate borehole volume <strong>and</strong> annular volume<br />
determinations for the required cement volume<br />
Identification of packer seats for sampling <strong>and</strong> testing<br />
FIAC Four Independent Arm Caliper Tool Specifications<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Maximum Temperature<br />
°F (°C)<br />
400<br />
(204.4)<br />
Weight<br />
lb (kg)<br />
310<br />
(140.6)<br />
3-66 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
SDDT St<strong>and</strong>-Alone DITS Directional Tool<br />
The SDDT st<strong>and</strong>-alone DITS directional tool is a full<br />
navigational package that consists of three orthogonal<br />
fluxgate accelerometers <strong>and</strong> three orthogonal<br />
magnetometers.<br />
Features<br />
An enormous amount of data is acquired while logging. The<br />
SDDT tool transmits this data to the surface unit via<br />
Length<br />
ft (m)<br />
12.5<br />
(3.8)<br />
<strong>Halliburton</strong>’s proven DITS digital interactive telemetry<br />
system.<br />
The SDDT tool provides accurate information to help<br />
determine tool position, motion, direction, <strong>and</strong> orientation<br />
within the borehole.<br />
SDDT St<strong>and</strong>-Alone DITS Directional Tool Specifications<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.9)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
240<br />
(108.9)<br />
Open-Hole <strong>Wireline</strong> <strong>Services</strong> 3-67
3-68 Open-Hole <strong>Wireline</strong> <strong>Services</strong>
Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
Formation Evaluation<br />
TMD-L Thermal Multigate Decay-Lithology<br />
Logging Tool<br />
The TMD-L tool is a new-generation pulsed-neutron<br />
logging tool which measures the thermal neutron capture<br />
cross-sections (sigma) of both the formation <strong>and</strong> the<br />
borehole. The sigma parameter is a measure of the ability of<br />
the formation to absorb thermal neutrons. Because of the<br />
strong correlation between the open-hole resistivity log <strong>and</strong><br />
the sigma log, the sigma log is considered to be the casedhole<br />
equivalent of the conductivity log.<br />
Using induced gamma spectroscopy <strong>and</strong> decay time<br />
measurement, the TMD-L tool determines oil saturation in<br />
reservoirs with high salinity. Reservoir monitoring includes<br />
measurement of initial <strong>and</strong> current fluid contacts <strong>and</strong><br />
predicts how the fluids will move in the future. Accurate<br />
monitoring of fluid movement in a producing hydrocarbon<br />
reservoir can also yield major economic benefits through<br />
improved recovery (such as better reservoir management,<br />
better placement of infill wells, <strong>and</strong> break-through deferral)<br />
as well as lower costs from fewer wells <strong>and</strong> reduced water <strong>and</strong><br />
gas h<strong>and</strong>ling.<br />
The TMD-L tool differs from the competition by applying<br />
alpha-processing which optimally combines near <strong>and</strong> far<br />
detector responses to provide a sigma curve with the<br />
accuracy of the far detector <strong>and</strong> the vertical resolution <strong>and</strong><br />
precision of the near detector.<br />
This leading-edge detector technology results in full<br />
spectrum monitoring for greater amounts of information,<br />
faster logging speeds, <strong>and</strong> higher accuracy.<br />
Applications<br />
Cased-hole formation evaluation<br />
Lithology determination<br />
Enhanced oil recovery monitoring<br />
Gas vs. tight determination<br />
Water-flow detection<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-1<br />
HAL9138<br />
Example of Gravel Pack Evaluation with Silicon Activation<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong>
Features<br />
Larger diameter detectors to produce higher count rates<br />
Recording of each detector's decay curve with 61 time<br />
gates; time gates span the entire burst cycle—from build<br />
up through decay<br />
A different background measurement scheme to sample<br />
the background more frequently<br />
Recording of gamma ray spectra for the far-spaced or<br />
near-spaced detectors during several time windows<br />
Ability to mount gamma ray detector below the<br />
generator <strong>and</strong> running the tool inverted to facilitate<br />
water-flow measurements<br />
Simultaneous inelastic <strong>and</strong> capture spectral<br />
measurements<br />
Modular hardware design allows custom configurations<br />
Accurate water saturation interpretation over a broad<br />
range of borehole conditions <strong>and</strong> porosities<br />
Improved interpretation to help distinguish between gas<br />
reservoirs <strong>and</strong> low-porosity formations<br />
Improved repeatability, lithology determination,<br />
enhanced oil recovery monitoring, <strong>and</strong> spectral waterflow<br />
determination<br />
Quality indicators for monitoring tool operation <strong>and</strong><br />
algorithm performance<br />
Combinable with st<strong>and</strong>ard PL sensors to provide<br />
extensive interpretation support, save time at the rig site,<br />
<strong>and</strong> provide special tool configurations for special<br />
challenges<br />
Identifies problems earlier to reduce production<br />
downtime<br />
Optimizes <strong>and</strong> verifies completions for improved<br />
production<br />
Can help recommend remedial activities, such as further<br />
stimulation or conformance operations to:<br />
– Optimize production<br />
– Estimate reserves for better financial planning<br />
– Explore old wells for additional reserves<br />
– Help maximize customer return on investment<br />
Associated Answer <strong>Products</strong><br />
SigmaSat sigma saturation analysis<br />
Chi Modeling® computation service<br />
TMD-L Thermal Multigate Decay-Lithology Logging Tool Specifications<br />
Length<br />
ft (m)<br />
18<br />
(5.5)<br />
Diameter<br />
in. (mm)<br />
1.6875<br />
(42.86)<br />
Maximum Pressure<br />
psi (Mpa)<br />
15,000<br />
(103.4)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
325<br />
(162.7)<br />
Weight<br />
lb (kg)<br />
70<br />
(31.75)<br />
4-2 Cased-Hole <strong>Wireline</strong> <strong>Services</strong>
RMT Elite Reservoir Monitor Tool<br />
The RMT Elite reservoir monitor tool is a unique throughtubing<br />
carbon/oxygen (C/O) system, offering two to three<br />
times higher measurement resolution than other throughtubing<br />
C/O logging systems. Its high-density Bismuth<br />
germanium oxide (BGO) detectors allow the RMT Elite tool<br />
to achieve resolutions previously available only with larger<br />
diameter C/O systems. As a result, the RMT Elite tool can be<br />
used to run continuous passes in low porosity formations<br />
where other systems can only be run in a stationary mode.<br />
The RMT Elite tool can also be conveyed into a well with<br />
tubing completions unlike larger C/O systems that can only<br />
log through casing.<br />
Utilizing induced gamma spectroscopy <strong>and</strong> decay time<br />
measurements, this pulsed-neutron device is primarily used<br />
to determine oil saturation in reservoirs. For reservoirs<br />
having low, mixed, or unknown salinity-formation water, the<br />
inelastic or C/O mode is used. For higher salinities, the<br />
capture mode is used, producing a TMD-L thermal<br />
multigate decay-lithology-type log. In addition, the RMT<br />
Elite tool can be used in either operating mode to perform<br />
elemental analyses from the measured spectra to identify<br />
lithology in all types of reservoirs.<br />
Because the RMT Elite tool is so accurate <strong>and</strong> precise, it<br />
allows operators to achieve logging speeds two to five times<br />
faster than competing systems.<br />
Applications<br />
Discriminate formation fluid contacts<br />
Evaluate hydrocarbon zone saturations in fresh, mixed,<br />
or unknown water salinity environments<br />
Locate water <strong>and</strong> oil zones in waterfloods where mixed<br />
salinities exist between formation <strong>and</strong> flood waters<br />
Evaluate saturations in formations behind casings when<br />
open-hole logs are not available<br />
Monitor steam <strong>and</strong> CO2 flood/breakthrough<br />
Inside/outside casing water detection<br />
Verify gravel pack integrity via silicon activation<br />
Accurately determine oil <strong>and</strong> gas saturations in high<br />
salinity or fresh water formations<br />
Identify bypassed reserves<br />
Pinpoint formation fluid contacts<br />
Identify lithologies <strong>and</strong> mineralogies<br />
HAL5680<br />
RMT Elite Primary Log Presentation—Track 1 of the display is used for<br />
plotting basic correlation curves. In this example the simultaneously<br />
recorded formation sigma <strong>and</strong> the potassium yield curve (YK) are plotted.<br />
Also plotted in the track is the oxygen activation curve (OAI), which is<br />
used to detect water flow. Track 2 of the log is used to display the raw<br />
carbon to oxygen ratio (COIR) <strong>and</strong> the calcium to silicon ratio (LIRI).<br />
The green shading between the curves is a quick look representation of<br />
hydrocarbons. Track 3 of the log displays yield curves computed from the<br />
capture spectra for silicon (YSi), calcium (YCa) <strong>and</strong> hydrogen (YH).<br />
Track 4 displays inelastic <strong>and</strong> capture near to far detector ratio curves.<br />
These curves are used to identify gas in the formation (shaded in red).<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-3
Features<br />
Below-tubing <strong>and</strong> in-tubing logging capability without<br />
sacrificing quality <strong>and</strong> accuracy<br />
2.125-in. tool size allows use of a large detector <strong>and</strong><br />
passage through 2.875-in. tubing<br />
Two detectors provide a near-to-far inelastic ratio,<br />
capture ratio, <strong>and</strong> two C/O measurements.<br />
Dual operating modes<br />
– Inelastic mode—(optimized for C/O formation<br />
measurements) C/O, elemental yields, ΣFM ,<br />
porosity from ratios, <strong>and</strong> oxygen activation<br />
– Capture mode—(optimized for Sigma formation<br />
measurements) ΣFM , elemental yields, porosity<br />
from ratios, <strong>and</strong> oxygen activation<br />
Accurately evaluates the time-lapse performance of<br />
hydrocarbon-producing reservoirs<br />
No well-kill fluids are necessary<br />
Associated Answer <strong>Products</strong><br />
RMT Elite tool data can be used alone in postlogging<br />
analysis, however, the addition of open-hole <strong>and</strong> cased-hole<br />
logging data often serves to enhance analysis results. For<br />
example, analysis options allow total <strong>and</strong> effective porosity to<br />
be computed from open-hole or cased-hole porosity data,<br />
TMD-L data, or external inputs. Also, a simple twoporosity<br />
log cross plot option is available to improve effective<br />
porosity estimates. Formation saturation analysis using the<br />
RMT Elite tool <strong>and</strong> porosity data can be provided via<br />
<strong>Halliburton</strong>’s cased-hole formation evaluation interpretation<br />
in the following software models.<br />
CarbOxSat model oil saturation analysis using C/O<br />
measurements<br />
SigmaSat model water saturation analysis using<br />
capture cross section measurements (Σ)<br />
TripleSat model three-phase oil, gas, <strong>and</strong> water<br />
saturations using both C/O <strong>and</strong> Σ measurements<br />
Chi Modeling® computation service<br />
Additionally, complex lithology <strong>and</strong> mineralogy answers can<br />
be provided by integrating RMT Elite tool elemental yield<br />
data in <strong>Halliburton</strong>’s ULTRA multi-mineral evaluation<br />
program software.<br />
Length<br />
ft (m)<br />
14.22<br />
(4.33)<br />
RMT Elite Quality Log Presentation—Track 1 of the presentation are<br />
curves that represent the accuracy of spectral gain stabilization measured<br />
from ratios of the iron edge (FERC) <strong>and</strong> the hydrogen peak (HPLI).<br />
Track 2 is a plot of the COIR <strong>and</strong> LIRI from the near space detector.<br />
Track 3 is used to plot additional yield curves computed from the capture<br />
spectra. Plotted on this example are the Iron yield (YFe) <strong>and</strong> the chlorine<br />
yield (YCl). Tracks 4 <strong>and</strong> 5 are used to plot the total inelastic <strong>and</strong> capture<br />
count rates for the near <strong>and</strong> far detectors. Track 6 is used to plot the<br />
simultaneous measured near formation sigma (SGFN) <strong>and</strong> the far<br />
formation sigma (SGFF).<br />
RMT Elite Reservoir Monitor Tool Specifications<br />
Diameter<br />
in. (mm)<br />
2.125<br />
(53.975)<br />
4-4 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL5681<br />
Maximum Pressure<br />
psi (Mpa)<br />
15,000<br />
(103.4)<br />
Maximum Temperature<br />
°F (°C)<br />
325<br />
(163)<br />
Weight<br />
lb (kg)<br />
77<br />
(34.9)
Spectra Flow Logging Service (SpFl)<br />
The Spectra Flow logging service directly detects <strong>and</strong><br />
evaluates water movement behind <strong>and</strong> inside the casing of<br />
both production <strong>and</strong> injection wells. The service is capable of<br />
measuring water-flow direction up <strong>and</strong> down, linear flow<br />
velocity, <strong>and</strong> volume flow rate of water moving vertically.<br />
Water velocity measurements using spectral data are<br />
provided with continuous logs <strong>and</strong> stationary impulse stepdown<br />
tests. Water-flow greater than 3 ft/min can be detected<br />
<strong>and</strong>, depending on the flow volume <strong>and</strong> location,<br />
quantitative velocities as low as 5 ft/min can be measured.<br />
For velocities over 50 ft/min, improved accuracy is obtained<br />
by using the more distant natural gamma ray detector. A<br />
modular tool design allows the Spectra Flow service to be run<br />
in combination with production logging tools. Multiple<br />
configuration options allow the service to be tailored to the<br />
types of flows encountered downhole.<br />
The Spectra Flow tool is a uniquely reconfigured pulseneutron<br />
capture/spectral through-tubing device with a<br />
source to detect spacing to make quantitative water-flow<br />
measurements. The tool has two logging methods—<br />
continuous logging <strong>and</strong> stationary impulse testing.<br />
This combination of high-resolution water detection plus<br />
unique pulsed-neutron timing allows the use of the<br />
continuous logging method. In this method, the linear<br />
velocity of water-flow is determined from the ratio of oxygen<br />
activation measured with the near <strong>and</strong> far detectors.<br />
The stationary impulse method is a travel time measurement<br />
that automatically switches the neutron generator on/off <strong>and</strong><br />
measures the fluid velocity with respect to time. Independent<br />
velocities are measured for each detector. Since calibration of<br />
the detectors is not required for measurement accuracy, this<br />
method has better results than any other system.<br />
Other logging techniques used to discover fluid movement<br />
behind the casing involve measuring acoustical noise,<br />
temperature, <strong>and</strong> radioactive tracers. Running one or a<br />
combination of these services can be done successfully, but<br />
the interpretation of the data is frequently not easy.<br />
Spectra Flow logs eliminate the need to inject tracer<br />
materials, have sufficient resolution, a deeper depth of<br />
investigation, <strong>and</strong> appear to be more practical for detecting<br />
low flow rates than traditional methods.<br />
The above Spectra Flow impulse velocity test calculates accurate velocity<br />
by measuring the time of activated water compared to nonactivated water<br />
passing by Spectra Flow detectors. Velocities are calculated for the two<br />
spectral measurements, the total activation measurement, <strong>and</strong> the natural<br />
gamma ray detector. Both simultaneous up <strong>and</strong> down flow can be<br />
measured. Track 3 displays the spectral measurements of activated oxygen.<br />
Track 2 contains the gamma ray, near <strong>and</strong> far oxygen activation (OAIN<br />
<strong>and</strong> OAIF), generator voltage, <strong>and</strong> near <strong>and</strong> far total activation<br />
measurement (TNA <strong>and</strong> TFA) curves. Track 1 shows the water-flow<br />
velocity curves from each of the measurements in Track 2 (VSN for OAIN,<br />
VSF for OAIF, VTN for TNA, VTF for TFA, <strong>and</strong> VGR for GR).<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-5<br />
HAL1031
Applications<br />
The detection <strong>and</strong> quantification of water flowing in<br />
cement channels (in producing or injection wells)<br />
Identification of water-flow between tubing <strong>and</strong> casing<br />
Detecting water entries<br />
Detecting thief zones<br />
Discovering cross flow between zones<br />
Detecting leaking plugs <strong>and</strong> packers<br />
CO2 flow measurements<br />
Features<br />
Specially designed for quantitative water-flow<br />
measurements<br />
Modified detector section for the pulsed neutron capture<br />
tool includes source-to-detector spacing to eliminate<br />
effects of stationary water in the borehole <strong>and</strong>/or the<br />
formation<br />
Fully combinable with a complete string of production<br />
log sensors<br />
Length<br />
ft (m)<br />
18<br />
(5.5)<br />
Modular design allows tool to be configured for<br />
detecting water sources from above or below; can also be<br />
configured to measure both up <strong>and</strong> down water sources<br />
simultaneously<br />
Pure spectral measurement isolates only gamma rays<br />
produced for oxygen recording<br />
Gamma rays produced as a result of oxygen activation<br />
are recorded spectrally, allowing elimination of all other<br />
sources of gamma rays<br />
Because it measures spectrally, it can determine<br />
Compton downscattering, allowing qualitative<br />
determination of whether flow is inside or outside the<br />
pipe<br />
Associated Answer <strong>Products</strong><br />
QW (Calculates water-flow rate <strong>and</strong> velocity)<br />
Spectra Flow Logging Service (SpFl) Specifications<br />
Diameter<br />
in. (mm)<br />
1.6875<br />
(42.8625)<br />
Maximum Pressure<br />
psi (Mpa)<br />
15,000<br />
(103.4)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
325<br />
(162.8)<br />
Weight<br />
lb (kg)<br />
4-6 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
70<br />
(31.8)
DSN Dual-Spaced Neutron Tool<br />
The DSN dual spaced neutron tool is a thermal neutron<br />
tool designed to measure formation porosity from neutronnuclei<br />
interactions. Neutron porosity logs provide total fluid<br />
information for use with resistivity logs <strong>and</strong>/or pulsed<br />
neutron logs in determining formation water saturation.<br />
They can be combined with density logs to provide an<br />
indication of formation gas saturation <strong>and</strong> also with density<br />
<strong>and</strong>/or sonic logs to provide indications of formation<br />
lithology. In open holes, the DSN tool is usually combined<br />
with the SDLT spectral density logging tool <strong>and</strong> the<br />
NGRT natural gamma ray tool. In cased holes, the<br />
DSN tool is usually combined with the NGRT tool <strong>and</strong><br />
DITS casing collar locator.<br />
The DSN tool consists of an instrument section housing the<br />
electronics, two He3 detectors, <strong>and</strong> a source sub housing an<br />
americium-beryllium source which generates fast neutrons<br />
that penetrate the formation at an initial energy of 4.6 MeV.<br />
Thermal neutron tools are not as limited by the spacing <strong>and</strong><br />
depth of investigation problems associated with epithermal<br />
neutron tools. Since thermal neutrons are detected, count<br />
rates are much higher than for epithermal neutrons.<br />
However, thermal neutron detectors are more sensitive to<br />
lithology <strong>and</strong> are affected by borehole <strong>and</strong> formation salinity.<br />
The dual detector method is used to compensate for these<br />
environmental effects.<br />
Applications<br />
Gas detection<br />
Porosity<br />
Lithology<br />
Features<br />
Detector array contains two helium proportional<br />
counters<br />
Optimized detector spacing, advanced calibration<br />
methods, <strong>and</strong> greater counting rates<br />
Faster log runs<br />
Delineation of thin-bed formations with enhanced<br />
vertical resolution (EVR) available in real-time or in<br />
post-processing<br />
A combination of logging tools can be run to identify<br />
lithology, reveal gas zones, <strong>and</strong> calculate shale volumes<br />
In this DSN log example, the subject well was logged twice. The<br />
resulting near/far ratio curves <strong>and</strong> the calculated porosity curves are<br />
overlaid to illustrate high repeatability of DSN porosity measurements.<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-7<br />
HAL1664
Associated Answer <strong>Products</strong><br />
The wellsite answer product is the neutron porosity<br />
NPHI<br />
Neutron porosity data is also used with other open-hole<br />
sensors as input to <strong>Halliburton</strong>’s mineralogy, open-hole,<br />
<strong>and</strong> cased-hole saturation analysis to provide a complete<br />
formation evaluation product. These include:<br />
Length<br />
ft (m)<br />
10.25<br />
(3.1)<br />
– ULTRA multi-mineral evaluation program<br />
– CORAL complex lithology analysis<br />
–LARA laminated reservoir analysis<br />
– SASHA shaly s<strong>and</strong> analysis<br />
DSN Dual-Spaced Neutron Tool Specifications<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
4-8 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
196<br />
(88.9)
FCMT Formation Compaction Monitoring Tool<br />
The FCMT formation compaction monitoring tool is a<br />
through-tubing instrument that can be run in production<br />
wells. The tool uses multiple gamma ray detectors to<br />
determine the location of <strong>and</strong> precise distance between<br />
radioactive markers planted in the formation or casing.<br />
Compaction of the formation can be measured by changes in<br />
the distance between the markers. Vertical compaction <strong>and</strong><br />
the lateral displacement of markers can also be monitored<br />
using the FCMT tool.<br />
Applications<br />
Determine the location of <strong>and</strong> precise distance between<br />
radioactive markers planted in the formation or casing<br />
Monitor vertical compaction <strong>and</strong> lateral displacement of<br />
markers<br />
Features<br />
Unique construction allows spacing between detectors to<br />
be easily altered to fit the application<br />
Available in three-detector or four-detector arrays to<br />
help make necessary configuration changes easy to<br />
implement<br />
Measures tool temperature to correct for thermal<br />
expansion<br />
Depth measurements are corrected for irregular tool<br />
motions using a uni-axial accelerometer<br />
A pair of induction-type casing collar locators (CCLs)<br />
provides additional compaction/depth measurements<br />
Length*<br />
ft (m)<br />
–<br />
* Specified by customer<br />
** Depends on configuration<br />
Track 1 consists of the processed gamma ray reading from detector 1. It<br />
shows the high spikes of the radioactive tags with the upper three tags<br />
being placed in the formation while the lower three tags were placed in<br />
the casing. Three different methods are used to determine spacing<br />
between radioactive tags. The next track shows the depth of each tag<br />
plus the distance between tags as calculated by special processing. This<br />
processing can be extremely accurate as long as the tag placement is<br />
close to the spacing between gamma ray detectors. The red numbers in<br />
Track 3 indicate the average of all the different methods to calculate<br />
distance between the tags. Track 4 is the average of all the methods less<br />
the HES method. The last track is raw gamma ray data from the three<br />
detectors. The tool configuration in this case consisted of three gamma<br />
ray detectors with 1 ft spacing between the first two detectors <strong>and</strong> 30 ft<br />
between the second <strong>and</strong> third. Distance between each detector is<br />
corrected for temperature affects <strong>and</strong> is used in the post-processing<br />
software.<br />
FCMT Formation Compaction Monitoring Tool Specifications<br />
Diameter<br />
in. (mm)<br />
1.68<br />
(42.7)<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-9<br />
HAL9762<br />
Maximum Pressure<br />
psi (Mpa)<br />
15,000<br />
(103.4)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight**<br />
lb (kg)<br />
–
CASE Casing Evaluation <strong>and</strong> Inspection Software<br />
CASE casing evaluation <strong>and</strong> inspection software is a series<br />
of programs that will use data from either the rotating<br />
ultrasonic tools (FASTCAST or CAST-V tools) or the<br />
multi-finger caliper tools to provide accurate casing<br />
evaluation. When the ultrasonic data is recorded in the<br />
casing mode, CASE software provides precise casing ID <strong>and</strong><br />
thickness presentations that allow easy interpretation of<br />
casing damage. When the ultrasonic data is acquired in the<br />
image mode or with multi-finger caliper tools, CASE<br />
software provides a detailed interpretation of the interior<br />
casing damage.<br />
With both the FASTCAST <strong>and</strong> CAST-V tools in the image<br />
mode, they can be used to monitor wear on the inner surface<br />
of the casing string. Its high vertical <strong>and</strong> horizontal<br />
resolutions nearly eliminate the chance of missing flaws in a<br />
string of pipe, thus preventing possible long-term problems.<br />
In the cased-hole mode, the ultrasonic tools provide accurate<br />
casing ID <strong>and</strong> casing thickness measurements. With these<br />
two measurements, it is possible to determine the total<br />
damage to the casing <strong>and</strong> proportionate it to either inside<br />
casing wear, outside casing corrosion, or a combination of<br />
the two.<br />
The CASE software family provides detailed information on<br />
the condition of the casing, preventing minor problems from<br />
becoming major problems. The software consists of several<br />
different programs to provide the best possible interpretation<br />
of casing damage.<br />
With both ultrasonic <strong>and</strong> caliper data, slight tool eccentering<br />
problems will lead to an inaccurate analysis. Spiral or<br />
patterns similar to a barbershop pole are indications of<br />
eccentricity problems, not necessarily casing wear. The<br />
program HoleShape corrects the travel time data for tool<br />
eccentering. The correction increases the detail of the travel<br />
time image leading to an improved visual interpretation of<br />
casing defects.<br />
The CASE program will use the corrected travel time, the<br />
pipe thickness, <strong>and</strong> fluid travel time to evaluate the casing<br />
condition <strong>and</strong> determine the percent of casing wear. With<br />
this program, the results are presented both calculated <strong>and</strong><br />
normalized for each size <strong>and</strong> weight of the casing present. If<br />
the casing is perfect (no damage in radius or thickness), then<br />
the normalized radius <strong>and</strong> thickness measurements will be<br />
zero. If the casing has internal corrosion, the radius<br />
measurement will be larger than the known, <strong>and</strong> the<br />
thickness will be smaller. Therefore, the normalized data will<br />
show the loss of casing wall as an increase in the pipe radius<br />
<strong>and</strong> a decrease in pipe thickness. This information allows us<br />
to grade the pipe based on the total loss of metal, <strong>and</strong> can<br />
determine if the damage is inside/outside or a combination<br />
of both for the casing in question. These grades are based on<br />
industry st<strong>and</strong>ards or can be adjusted based on customer<br />
requirements.<br />
The final program in this family is the CASE_JOINT<br />
program that finds, counts, <strong>and</strong> displays data based on each<br />
joint. For casing evaluation, collars provide problems with<br />
the st<strong>and</strong>ard casing analysis logs. There are usually gaps<br />
between adjacent joints, additional metal in the collars, <strong>and</strong><br />
possible damage near the collars from when the joints were<br />
made up. This program will determine the joint makeup<br />
point, <strong>and</strong> allow determination of both joint <strong>and</strong> collar<br />
damage based on the grading used in CASE software.<br />
The CHIME program combines all these programs <strong>and</strong> also<br />
has the ability to provide graphical displays of damage from<br />
both the ultrasonic <strong>and</strong> caliper tools. In addition, the CASE<br />
programs generate both spreadsheets <strong>and</strong> text files that list<br />
minimum, maximum, <strong>and</strong> average values of both the<br />
internal radius <strong>and</strong> the thickness of the casing not only on a<br />
joint-by-joint listing but also as a depth-by-depth listing.<br />
These files will allow continuous monitoring <strong>and</strong><br />
comparisons of casing wear throughout the life of the well.<br />
Features<br />
Delivers a more reliable indication of casing condition<br />
Works with existing logging procedures for FASTCAST,<br />
CAST-V, <strong>and</strong> MIT tool data<br />
Improves casing evaluation for both inner <strong>and</strong> outer<br />
defects<br />
Corrects for tool eccentricity thus helping to distinguish<br />
even minute casing problems<br />
Log presentations can be customized to meet the specific<br />
requests or needs. Presentations include raw data,<br />
segmented curves, <strong>and</strong> images, including 3D displays<br />
Joint <strong>and</strong> depth listings of defects allow easy input into<br />
other programs or a simple method to monitor known<br />
casing deformities<br />
Health, Safety, <strong>and</strong> Environmental<br />
Helps customers to monitor <strong>and</strong> prevent catastrophic<br />
casing problems<br />
Proper CASE software usage allows monitoring of casing<br />
erosion / corrosion / rectification<br />
4-10 Cased-Hole <strong>Wireline</strong> <strong>Services</strong>
Y000<br />
Y030<br />
Y050<br />
This CASE processed log effortlessly shows where a packer was set <strong>and</strong> did not release properly. The metal was peeled up when the packer was pulled,<br />
which is highlighted by the green stripe box in the depth track. This zone is exp<strong>and</strong>ed on the log on the left. Track 1 provides gamma ray for correlation<br />
along with eccentricity <strong>and</strong> ovality. Eccentricity consists of tool <strong>and</strong> casing eccentricity, while ovality measures casing ovality. INTDAMG is the percent<br />
of pipe wear on a scale from 0 to 50 percent. The AVRAD is the average radius calculated from the 200 radius measurements from the CAST-V tool.<br />
Track 2 is the amplitude of the first arrival <strong>and</strong> can be used to visually indicate casing damage. Track 3 is an eccentricity corrected travel time for the first<br />
arrival. This will be used in determining casing ID or radius. Track 4 shows the minimum, maximum, <strong>and</strong> average of the normalized pipe radius<br />
PRADN. The normalized pipe radius is shown in Track 5 where red is showing the packer damage <strong>and</strong> blue is showing metal buildup from the packer<br />
damage. The last track shows the pipe grading where the damage is color coded with the following percentages: white< 20%
Through Casing Acoustic <strong>Services</strong><br />
WaveSonic ® Tool<br />
The WaveSonic® crossed dipole sonic tool provides<br />
simultaneous monopole, XX dipole, <strong>and</strong> YY dipole sonic<br />
measurements. The dipole flexural wave propagation allows<br />
for the measurement of shear wave slowness in virtually all<br />
formation conditions. The compressional P-wave slowness,<br />
refracted shear wave slowness, <strong>and</strong> Stoneley wave properties<br />
are obtained from the monopole data. The shear wave<br />
slowness in two orthogonal directions can be obtained in<br />
real- time from the XX <strong>and</strong> YY dipole data. The WaveSonic<br />
tool is combinable with all st<strong>and</strong>ard open <strong>and</strong> cased-hole<br />
tool services. The WaveSonic tool requires a liquid filled<br />
borehole <strong>and</strong> can be used in fresh water, salt water, or oil<br />
based mud systems. The robust mechanical design of this<br />
tool allows for drillpipe conveyed logging, <strong>and</strong> it is not<br />
limited to the bottom of the toolstring. A hostile WaveSonic®<br />
version is available for high temperature <strong>and</strong> high pressures<br />
applications.<br />
The shear wave slowness in the XX <strong>and</strong> YY directions <strong>and</strong> the<br />
monopole P-wave slowness are the basic well site<br />
deliverables. The tool has 32 broadb<strong>and</strong> receivers, arranged<br />
in eight rings of four receivers, to provide high-quality<br />
waveform data. The tool provides 96 waveforms (32<br />
monopole, 32 YY dipole, <strong>and</strong> 32 XX dipole) for each firing<br />
cycle, which are recorded by the surface system. The fast <strong>and</strong><br />
slow shear wave travel times are obtained with advanced<br />
waveform processing methods in <strong>Halliburton</strong>'s Reservoir<br />
Evaluation <strong>Services</strong> centers, strategically located throughout<br />
the world.<br />
From the fast <strong>and</strong> slow shear wave travel times, <strong>and</strong> their<br />
orientation in the formation, the minimum <strong>and</strong> maximum<br />
principal stresses <strong>and</strong> stress field orientation can be obtained<br />
by combining oriented slowness data with overburden <strong>and</strong><br />
analysis, wellbore stability, <strong>and</strong> production enhancement<br />
treatment design.<br />
Natural gamma ray <strong>and</strong> caliper are presented in Track 1. Semblance<br />
quality data is presented in the depth track. The dipole X travel time,<br />
dipole Y travel time, <strong>and</strong> monopole P-wave travel time are presented in<br />
Track 2. Monopole semblance with the compressive wave slowness<br />
overlaid on the semblance image are presented in Track 3. The dipole X<br />
semblance with the XX shear wave slowness overlaid on the semblance<br />
image are presented in Track 4. The dipole Y semblance with the YY<br />
shear wave slowness overlaid on the semblance image are presented in<br />
Track 5.<br />
4-12 Cased-Hole <strong>Wireline</strong> <strong>Services</strong>
Sonic anisotropy analysis provides the fast <strong>and</strong> slow shear<br />
wave travel times as a simultaneous solution of 64<br />
waveforms(32 XX <strong>and</strong> 32 YY). Anisotropy <strong>and</strong> its orientation<br />
can be used to determine the minimum horizontal stress <strong>and</strong><br />
the orientation of natural fractures. The sonic attributes of<br />
slowness, amplitude <strong>and</strong> frequency content can be used for<br />
identification of fractures <strong>and</strong> compressive fluids <strong>and</strong> to<br />
measure various geomechanical properties. The fast <strong>and</strong> slow<br />
shear wave travel times <strong>and</strong> their orientation, combined with<br />
P-wave slowness, allows for better 3D seismic analysis.<br />
Applications<br />
Determine fast <strong>and</strong> slow wave travel times <strong>and</strong><br />
orientation in the formation<br />
Calculate minimum <strong>and</strong> maximum principal stresses<br />
<strong>and</strong> stress field orientation<br />
Porosity estimation<br />
Fracture identification<br />
Permeability (mobility) estimation<br />
AVO calibration<br />
Synthetic seismogram<br />
Features<br />
Programmable-frequency sources to minimize effects of<br />
near-wellbore alteration<br />
Length<br />
ft (m)<br />
Tool<br />
Version<br />
34.0<br />
(10.3)<br />
20 KPSI<br />
Tool<br />
30 KPSI<br />
Tool<br />
Length<br />
ft (m)<br />
40.9<br />
(12.4)<br />
40.9<br />
(12.4)<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
WaveSonic ® Tool Specifications<br />
Maximum Pressure<br />
psi (mpa)<br />
20,000<br />
(137.9)<br />
Broadb<strong>and</strong> eight-level, quad receiver array for highquality<br />
waveform data<br />
All 96 waveforms for each set of transmitter firings are<br />
recorded at the surface for advanced waveform<br />
processing techniques<br />
Combinable with all open-hole tools, including MRIL®<br />
<strong>and</strong> RDT tools <strong>and</strong> services<br />
Associated Answer <strong>Products</strong><br />
Shear slowness anisotropy analysis<br />
RockXpert2 s<strong>and</strong> production <strong>and</strong> fracture strength<br />
analysis<br />
FracXpert fracture stimulation zoning analysis pore<br />
pressure data information is vital for geo-mechanical<br />
Instantaneous waveform attributes<br />
Stoneley derived permeability<br />
Stoneley reflection analysis<br />
Formation stress, borehole stability <strong>and</strong> s<strong>and</strong>ing<br />
potential<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Hostile WaveSonic ® Tool Specifications<br />
Diameter<br />
in. (mm)<br />
3.13<br />
(79.4)<br />
3.13<br />
(79.4)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
30,000<br />
(206.8)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
500<br />
(260.0)<br />
500<br />
(260.0)<br />
Weight<br />
lb (kg)<br />
520<br />
(236.3)<br />
Weight<br />
lb (kg)<br />
595<br />
(269.9)<br />
720<br />
(326.6)<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-13
FWS Full Wave Sonic Tool<br />
The FWS tool provides compressional wave, refracted<br />
shear wave, <strong>and</strong> Stoneley wave properties of downhole<br />
formations for a wide range of petrophysical, geological, <strong>and</strong><br />
geophysical applications. To minimize the number of logging<br />
trips required for complete formation evaluation, the FWS<br />
tool is compatible with all DITS logging tool strings. A<br />
liquid-filled borehole is required for sonic logging <strong>and</strong> can be<br />
used in fresh water, salt water, or oil-based mud systems.<br />
The long transmitter-to-receiver offset allows for the<br />
acquisition of borehole sonic data beyond the effects of any<br />
near-wellbore altered region. This long offset also allows for<br />
the acquisition of high-quality sonic data in enlarged<br />
boreholes where critical angle effects would affect sonic tools<br />
with short transmitter-to-receiver offsets.<br />
The information obtained from the FWS tool is plotted in<br />
three separate log presentations:<br />
Slowness presentation – compressional slowness <strong>and</strong><br />
refracted shear slowness, velocity ratio, <strong>and</strong> time-depth<br />
integration of the compressional <strong>and</strong> shear travel times,<br />
<strong>and</strong> other logging data such as gamma ray <strong>and</strong> caliper<br />
Quality presentation – indicators which establish<br />
confidence levels for the slowness processing, including<br />
compressional slowness <strong>and</strong> semblance coherency <strong>and</strong><br />
refracted shear <strong>and</strong> semblance quality gain curves for<br />
each receiver<br />
Waveform presentation – waveforms from all four<br />
receivers can be presented. Gain curves reflecting the<br />
gain applied to the waveform by the automatic gain<br />
control (AGC) circuit, <strong>and</strong> correlation curves, including<br />
gamma ray <strong>and</strong> caliper information<br />
The FWS tool can be run in the cased-hole environment to<br />
obtain sonic properties through casing. Acoustic coupling of<br />
the pipe-to-formation is required for cased-hole<br />
applications.<br />
Applications<br />
Identify wave properties of downhole formations<br />
Acquisition of borehole sonic data<br />
The natural gamma ray, X-X caliper, Y-Y caliper, P-wave travel time <strong>and</strong><br />
P-wave semblance quality are presented in Track 1. The monopole<br />
waveform data is presented in Track 2 in the MicroSeismogram format<br />
(X-Z) <strong>and</strong> in an X-Y waveform presentation in Track 3.<br />
4-14 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL9170
Features<br />
Long transmitter-to-receiver offsets <strong>and</strong> 1 ft<br />
receiver-to-receiver spacings<br />
Detection of signals at all receivers for each transmitter<br />
pulse ensures constant source characteristics<br />
Automatic gain control of each receiver preserves signal<br />
amplitude<br />
Downhole digitizing helps eliminate transmission noise<br />
<strong>and</strong> allows broadb<strong>and</strong> frequency response<br />
Low-frequency response allows detection of low<br />
frequency Stoneley waves <strong>and</strong> multiple Δt measurements<br />
per depth interval<br />
Continuous uninterrupted recording of full waveform<br />
signals<br />
Records various types of information including tool<br />
data, quality curves, <strong>and</strong> final results<br />
Operator-selectable multiple modes of tool operation,<br />
digitally recorded waveform data, <strong>and</strong> improved porosity<br />
estimates using both Δtc <strong>and</strong> Δts Length<br />
ft (m)<br />
28.6<br />
(8.7)<br />
FWS Full Wave Sonic Tool Specifications<br />
Diameter<br />
in. (mm)<br />
3.625<br />
(92.1)<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Lithology identification by means of velocity ratio, Δts/ Δtc, <strong>and</strong> location of gas zones, even in poor hole<br />
conditions <strong>and</strong> cased holes<br />
Indication of permeability variations with depth from<br />
Stoneley wave attenuation <strong>and</strong> slowness<br />
Detection of naturally fractured zones, determination of<br />
rock elastic constants, <strong>and</strong> estimation of formation<br />
strength <strong>and</strong> least horizontal stress<br />
Prediction of vertical extent of hydraulic fractures<br />
Improved vertical resolution for detection of thinner<br />
beds (Beds as thin as 3 in. can be identified with the t<br />
curves)<br />
Calculates sonic porosity from P-wave slowness <strong>and</strong> can<br />
determine secondary porosity by combining sonic<br />
porosity with neutron <strong>and</strong> density porosity data<br />
Time-to-depth correlation for seismic correlation<br />
Combining sonic slowness data with formation density<br />
data is the required input information needed for<br />
synthetic seismograms<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
460<br />
(208.7)<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-15
HFWS Hostile Full Wave Sonic Tool<br />
The HFWS tool is a 2.75-in. acoustic velocity logging tool<br />
that is a part of the HEAT suite hostile environment<br />
applications tool toolstring. The HFWS tool, along with all of<br />
the HEAT suite sensors, have a pressure rating of 25,000 psi<br />
(172 400 kPa). The HEAT suite logging tools are designed for<br />
continuous operation of six hours at 500°F (260°C).<br />
The HFWS tool, like the larger in diameter (3.625-in.)<br />
FWS full wave sonic tool, provides compressional wave,<br />
refracted shear wave, <strong>and</strong> Stoneley wave properties of<br />
downhole formations for a wide range of petrophysical,<br />
geological, <strong>and</strong> geophysical applications. To minimize the<br />
number of logging trips required for complete formation<br />
evaluation, the HFWS tool is compatible with all HEAT suite<br />
logging toolstrings. A liquid filled borehole is required for<br />
sonic logging, <strong>and</strong> can be used in fresh water, salt water, or<br />
oil-based mud systems.<br />
The HFWS tool can be compared to having two sonic tools<br />
within the same toolstring—a long-spaced sonic tool for<br />
traditional full waveform open-hole sonic logging, <strong>and</strong><br />
located within the transmitter-to-receiver offset, a cement<br />
bond tool that utilizes the second transmitter <strong>and</strong> two<br />
receivers. The upper transmitter <strong>and</strong> the lower four receivers<br />
array are utilized for full wave sonic logging. The lower<br />
(second) transmitter <strong>and</strong> the upper two receivers are utilized<br />
for cement bond logging <strong>and</strong> short, offset compressional<br />
wave travel time. The long transmitter-to-receiver offset<br />
allows for the acquisition of borehole sonic data beyond the<br />
effects of any near-wellbore altered region. The long offset<br />
also allows for the acquisition of high-quality sonic data in<br />
enlarged boreholes where critical angle effects would affect<br />
sonic tools with short transmitter-to-receiver offsets.<br />
Applications<br />
Full waveform open-hole sonic logging<br />
Cement bond logging<br />
Acquisition of borehole sonic data<br />
The natural gamma ray, X-X caliper, Y-Y caliper, P-wave travel time <strong>and</strong><br />
P-wave semblance quality are presented in Track 1. The monopole<br />
waveform data is presented in Track 2 in the MicroSeismogram format<br />
(X-Z) <strong>and</strong> in an X-Y waveform presentation in Track 3.<br />
4-16 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL9171
Features<br />
Advanced system design <strong>and</strong> software processing with<br />
long transmitter-to-receiver offsets <strong>and</strong> 1/2 ft receiver-toreceiver<br />
spacings<br />
Detection of signals at all receivers for each transmitter<br />
pulse to promote constant source characteristics<br />
Automatic gain control of each receiver helps preserve<br />
signal amplitude<br />
Downhole digitizing helps eliminate transmission noise<br />
<strong>and</strong> allows broadb<strong>and</strong> frequency response<br />
Low-frequency response allows detection of low<br />
frequency Stoneley waves <strong>and</strong> multiple Δt measurements<br />
per depth interval<br />
Facilitates continuous uninterrupted recording of full<br />
waveform signals<br />
Ability to record various types of information including<br />
tool data, quality curves, <strong>and</strong> final results<br />
Operator-selectable multiple modes of tool operation,<br />
digitally recorded waveform data, <strong>and</strong> improved porosity<br />
estimates using both Δtc <strong>and</strong> Δts Facilitates lithology identification by means of velocity<br />
ratio, Δts /Δtc , <strong>and</strong> location of gas zones, even in poor<br />
hole conditions <strong>and</strong> cased holes<br />
Indication of permeability variations with depth from<br />
Stoneley wave attenuation <strong>and</strong> Δt<br />
Detection of naturally fractured zones, determination of<br />
rock elastic constants, <strong>and</strong> estimation of formation<br />
strength <strong>and</strong> least horizontal stress<br />
Prediction of vertical extent of hydraulic fractures using<br />
the RockXpert2 analysis package<br />
Improved vertical resolution for detection of thinner<br />
beds (Beds as thin as 3-in. can be identified with the<br />
t curves)<br />
Time-to-depth correlation for seismic correlation<br />
Combining sonic slowness data with formation density<br />
data are the required input information for synthetic<br />
seismograms<br />
Length*<br />
ft (m)<br />
30.2<br />
(9.2)<br />
HFWS Hostile Full Wave Sonic Specifications<br />
Diameter<br />
in. (mm)<br />
2.75<br />
(69.9)<br />
Maximum Pressure<br />
psi (Mpa)<br />
25,000<br />
(172.4)<br />
* Add 3.50 ft (1.1 m) for each in-line centralizer (usually two).<br />
**6 hour<br />
Gamma ray <strong>and</strong> caliper are presented in Track 1, compressional wave<br />
travel time (DTC) is presented in Track 4, <strong>and</strong> the P-wave semblance<br />
quality is presented in Track 3.<br />
This is a hard rock example. Natural gamma ray, caliper, <strong>and</strong> VpVs<br />
are presented in Track 1. The P-wave travel time <strong>and</strong> the refracted<br />
shear wave travel time are presented in Track 2. The semblance<br />
quality is presented in an image format in Track 3 for the P-wave<br />
<strong>and</strong> refracted shear wave.<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-17<br />
HAL9172<br />
HAL9173<br />
Maximum Temperature**<br />
°F (°C)<br />
500<br />
(260)<br />
Weight<br />
lb (kg)<br />
340<br />
(154.2)
Production Logging<br />
Production Logging Tools<br />
A wide range of production logging tools for use in all type of<br />
downhole environments are available:<br />
Production logging tools for vertical, deviated, <strong>and</strong><br />
horizontal wells<br />
Full range of sensors <strong>and</strong> running hardware for memory<br />
<strong>and</strong> electric line PL logging<br />
Applications<br />
Flow rate measurements – continuous flowmeters,<br />
basket flowmeters, fullbore flowmeters, spinner array<br />
tool (SAT)<br />
Fluid identification / flow composition tools – gas<br />
holdup, capacitance water holdup, radioactive fluid<br />
density, differential pressure density, capacitance array<br />
Flow condition / well diagnostic tools – pressure,<br />
temperature, X-Y caliper, inclinometer<br />
Correlation tools – gamma ray, casing collar locator<br />
Memory Production Logging<br />
The memory production logging string is normally deployed<br />
on slickline or coiled tubing. Simultaneous telemetry<br />
transmits the signals from st<strong>and</strong>ard sensors to a battery<br />
powered memory tool at the top of the toolstring. The<br />
memory tool is programmed using a computer <strong>and</strong><br />
interfaces to record log values with intervals as short as 0.1<br />
seconds or as long as many hours between readings.<br />
Once the logging operation is complete, the procedure for<br />
merging the log-time <strong>and</strong> depth-time data is rapid.<br />
Electric Line Production Logging<br />
Using a computerized LOGIQ-CH system, calibration,<br />
recording, <strong>and</strong> printing of well logs can be done in real time.<br />
When operating in this mode, the downhole telemetry<br />
transfers data from the toolstring to the surface system via<br />
electric line.<br />
This example provides a display of typical production logging tool data.<br />
For a complete interpretation temperature, pressure, holdup, <strong>and</strong> fluid<br />
velocity readings are necessary. Track 1 consists of the gamma ray (GR1),<br />
pressure (PR1), <strong>and</strong> temperature (TEMP1). The pressure data shows that<br />
this well has not achieved a steady production rate at this time. Tracks 2<br />
through 4 provide data concerning the fluid holdup as measured by the<br />
CAT tool, radioactive fluid density, <strong>and</strong> fluid capacitance tool. Tracks 5<br />
<strong>and</strong> 6 provide information about the fluid movement <strong>and</strong> cable speed.<br />
Track 2 consists of the average capacitance reading from four different<br />
passes of the CAT tool. Higher readings indicate hydrocarbons while water<br />
is around 450 counts or the right side of the track. Track 3 is the fluid<br />
density from four passes of the radioactive fluid density tool. Likewise,<br />
Track 4 consists of four passes of the fluid capacitance tool where low<br />
counts indicate water while the higher counts indicate hydrocarbons.<br />
Track 5 consists of four passes of the continuous spinner with pass 1 <strong>and</strong> 2<br />
showing a nonsteady state. Track 6 shows the speed of the tool, <strong>and</strong> since<br />
the well was logged with a coiled tubing the two speeds are about 30 fpm<br />
down <strong>and</strong> 20 fpm up.<br />
4-18 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL9253
Features<br />
Great selection of flowmeter types <strong>and</strong> sizes, including<br />
the SAT tool for deviated or horizontal wells<br />
High sensitivity <strong>and</strong> low threshold velocity flowmeters<br />
St<strong>and</strong>ard <strong>and</strong> compact tool sizes<br />
Multiple logging sensors in one string. All PL sensors can<br />
run simultaneously except the bottom only tools<br />
Advanced sensors such as the GHT gas holdup tool,<br />
CAT capacitance array tool, <strong>and</strong> spinner array tool<br />
(SAT) for horizontal <strong>and</strong> undulating wells<br />
Conveyance flexibility – toolstring can be deployed on<br />
electric line, slickline, coiled tubing, or drillpipe<br />
PL Tool<br />
Category Tool Type<br />
Casing Collar<br />
Locator<br />
Correlation<br />
Flow<br />
Condition /<br />
Well<br />
Diagnostic<br />
Fluid<br />
Identification<br />
Production Gamma<br />
Ray<br />
Dual Caliper<br />
Quartz Pressure<br />
Gauge<br />
Fast Response<br />
Platinum Resistance<br />
Thermometer<br />
Inclinometer<br />
Accelerometer<br />
Enhanced<br />
Capacitance Water<br />
Holdup Tool<br />
Radioactive Fluid<br />
Density Tool<br />
Differential Pressure<br />
Fluid Density Tool<br />
Capacitance Array<br />
Tool<br />
Gas Holdup Tool<br />
Greater consistency of data sets as a result of using the<br />
same sensors for electric line <strong>and</strong> memory operations<br />
Faster telemetry, accurate, safe, reliable operations<br />
The same telemetry platform is used to run production<br />
logging tools with casing inspection <strong>and</strong>/or pulse<br />
neutron tools, either sequentially in one trip in the hole<br />
or simultaneously if required<br />
Associated Answer <strong>Products</strong><br />
Hard copy log of multiple sensor measurements<br />
Wellsite production log analysis<br />
Advanced production log analysis at Applied Formation<br />
Evaluation Centers<br />
Production Logging Tools Specifications Summary<br />
Tool<br />
Length<br />
in. (mm)<br />
18.5<br />
(470)<br />
Range of Measurement Resolution Accuracy<br />
23.1<br />
(586)<br />
37.5<br />
(953)<br />
19.01<br />
(483)<br />
12.5<br />
(318)<br />
10.7<br />
(272)<br />
26.2<br />
(665)<br />
22.9<br />
(582)<br />
51.9<br />
(1318)<br />
51.43<br />
(1306)<br />
24<br />
(610)<br />
Sensitivity<br />
Threshold<br />
20 keV approx.<br />
2 to 9 in. 0.015 in.<br />
0 to 15,000 psi<br />
50 to 350°F (10 to 177°C)<br />
0.008 psi <strong>and</strong><br />
PL Tool<br />
Category Tool Type<br />
Flowmeter<br />
Combination<br />
Tool<br />
Deployment<br />
Tools<br />
Inline Spinner<br />
Flowmeter<br />
Continuous Spinner<br />
Flowmeter (Bearing)<br />
Continuous Spinner<br />
Flowmeter (Jeweled)<br />
Caged Full Bore<br />
Flowmeter<br />
3 Arm<br />
Caged Full Bore<br />
Flowmeter<br />
6 Arm<br />
Diverter Flowmeter<br />
Spinner Array Tool<br />
Quartz Pressure<br />
CCL<br />
Capacitance /<br />
Temperature / Flow<br />
Head Tension Unit<br />
Roller Centralizer<br />
Spring Centralizer<br />
Swivel<br />
Knuckle Joints<br />
Production Logging Tools Specifications Summary<br />
Tool<br />
Length<br />
in. (mm) Range of Measurement Resolution Accuracy<br />
21<br />
(533)<br />
9<br />
(229)<br />
34.9<br />
(886)<br />
34.9<br />
(886)<br />
70.7<br />
(1796)<br />
46<br />
(1168)<br />
19.01<br />
(483)<br />
Approx.<br />
18.5<br />
(470)<br />
w/o flow<br />
mech<br />
section<br />
22.8<br />
(580)<br />
Max fluid velocity 3,450 ft/min<br />
Max fluid velocity 2,000 ft/min<br />
Max fluid velocity 3,450 ft/min<br />
500 ft/min (2.54 m/s), 28,250 BPD<br />
in 7-in. casing; with solid shaft tool<br />
can work up to 1,200 ft/min<br />
500 ft/min (2.54 m/s), 28,250 BPD<br />
in 7-in. casing; with solid shaft tool<br />
can work up to 1,200 ft/min<br />
Minimum 6-8 m 3 per day. Maximum<br />
approx. 400 m 3 /d (6 psi drop<br />
~120 lb uplift in 5 1/2-in. casing)<br />
3 1/2 to 7-in. casing<br />
Threshold<br />
approx 8 ft/min<br />
in water<br />
Threshold<br />
approx 5 ft/min<br />
in water<br />
Threshold<br />
approx 5 ft/min<br />
in water<br />
1.7 ft/min approx<br />
(0.01m/s),<br />
100 BPD in 7-in.<br />
casing<br />
1.7 ft/min approx<br />
(0.01m/s),<br />
100 BPD in<br />
7-in. casing<br />
Threshold<br />
approx 8 ft/min<br />
in water<br />
12 ft/min in<br />
water<br />
Same as quartz pressure gauge <strong>and</strong> CCL individual tools<br />
10 pulses/rev<br />
10 pulses/rev<br />
10 pulses/rev<br />
10 pulses/rev<br />
10 pulses/rev<br />
10 pulses/rev<br />
3/8-in. spinner<br />
3 pulses/rev<br />
Same as capacitance / temperature flow individual tool. Flowmeter<br />
mechanical section can be any type of continuous or full bore flowmeter.<br />
-400 kg (compr.) to +1000 kg<br />
Hysteresis<br />
5% FS<br />
Temperature<br />
Drift 5% FS<br />
4-20 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
10.6<br />
(4.8)<br />
3.5<br />
(1.6)<br />
mechanical<br />
section only<br />
3.5<br />
(1.6)<br />
mechanical<br />
section only<br />
10<br />
(4.5)<br />
10<br />
(4.5)<br />
Approx 15<br />
(6.8)<br />
8.8<br />
(4.0)<br />
Approx 5.4<br />
(2.5)<br />
w/o flow<br />
mech section<br />
10<br />
(4.5)<br />
Spinner shroud<br />
OD 1 11/16,<br />
2 1/8, 3 1/8 in.<br />
Spinner shroud<br />
OD 1 11/16,<br />
2 1/8, 3 1/8 in.<br />
Spinner shroud<br />
OD 1 11/16,<br />
2 1/8, 3 1/8 in.<br />
Available for<br />
different casing<br />
size<br />
4 1/2 to 9 5/8 in.<br />
(114 to 244 mm)<br />
Available for<br />
different casing<br />
size<br />
4 1/2 to 9 5/8 in.<br />
(114 to 244 mm)<br />
3 1/2 to 9 5/8 in.<br />
(90 to 244 mm)<br />
6 miniature<br />
spinner equispaced<br />
around<br />
circumference<br />
Repeatability<br />
±2% FS<br />
Different roller centralizers are available with 3 or 4 arms with single or double rollers in each arm. Also have different<br />
centralization force as per operational requirement. Approx Length - 33.25 in. (845 mm) <strong>and</strong> weight around 12 lb.<br />
Different compact spring bows are available with 3 to 6 springs. Also have different centralization force as per<br />
operational requirement. Approx Length - 28 in. (711 mm) <strong>and</strong> weight around 10 lb.<br />
This is a monoconductor swivel joint which allows free rotation between the upper <strong>and</strong> lower heads while maintaining<br />
electrical continuity through the tool. Different sizes available, Approx Length - 11 in. (280 mm) <strong>and</strong> weight 4 lb.<br />
7<br />
(178)<br />
Ball type knuckle for deployment in<br />
deviated well<br />
Weight<br />
lb (kg) Others<br />
1. Tools specified have nominal OD of 1 1//16 in. Tools with OD of 1 3/8 in. are also available.<br />
2. All tools have maximum pressure rating of 15,000 psi <strong>and</strong> maximum temperature rating of 350°F or 177°C. For higher pressure or higher temperature tools<br />
contact your local <strong>Halliburton</strong> representative.<br />
3. Telemetry is very high speed capable of running 62 tools in combination (virtually no limit on tool combination for telemetry).<br />
3.5<br />
(1.6)
FloImager ® Service<br />
The FloImager® service provides three-phase holdup<br />
calculations using data from the CAT capacitance array<br />
tool. This service is extremely useful in highly deviated <strong>and</strong><br />
horizontal wells having multiphase flow. Applications for<br />
detecting three-phase fluid entry can be done at any angle.<br />
The CAT tool is an electric line, tractor, or coiled tubing<br />
conveyed production logging instrument developed in<br />
partnership with Sondex. It consists of an array of 12 microcapacitance<br />
sensors which are radially distributed in the<br />
wellbore to accurately measure fluid holdup. This holdup<br />
measurement is fullbore. Consequently, tool position does<br />
not affect the readings in horizontal wells as would be the<br />
case with a center sample device.<br />
The CAT tool is uniquely versatile in that sensors are<br />
distributed across 12 bow springs, allowing cross-sectional<br />
measurements in tubing <strong>and</strong> in casing, logging up or logging<br />
down. This process can be repeated as often as necessary.<br />
Readings can also be taken with the tool stationary at any<br />
depth. The CAT tool can be run in combination with the<br />
spinner array tool (SAT), reservoir monitoring tools, <strong>and</strong><br />
other conventional production logging sensors.<br />
Applications<br />
Detect water entry <strong>and</strong> its orientation relative to the high<br />
side of the pipe in any well deviation<br />
Successfully show three-phase fluid segregation since<br />
each fluid has its own log response<br />
Provide an accurate visualization of the undulating<br />
horizontal wellbore when TVD data is combined with<br />
CAT tool data<br />
Allows a complete three-phase analysis by combining the<br />
calculated fluid holdup with additional PL sensors<br />
Improve interpretation of flow patterns in all wells due to<br />
the increased number of sensors at the same depth. Since<br />
the relative position of the CAT tool is known at all<br />
times, the images <strong>and</strong> logs are corrected to the high side<br />
of the hole, allowing accurate holdups to be determined<br />
Track 1 consists of a gamma ray (GR), relative bearing (RB), temperature<br />
(TEMP), pressure (PRES), <strong>and</strong> continuous spinner (FCON). RB is the<br />
relative bearing for arm 1 of the CAT tool <strong>and</strong> allows arm position<br />
relative to the high side of the hole to be determined. Track 2 provides the<br />
image of the flow as measured by the CAT tool. The image is positioned so<br />
that the high sides are on the left <strong>and</strong> right side of the track while the<br />
middle is on the low side. Since this is a horizontal well, it should be<br />
apparent that the heavier fluids should be on the bottom <strong>and</strong> lighter fluids<br />
should be on the top of the well. Track 3 shows the average of the 12<br />
sensors (AVCAPN) along with the two center sample holdup<br />
measurements fluid density (FDEN) <strong>and</strong> Hydro tool (HYDR). Track 4<br />
provides a cross-sectional view of the data in Track 2. The right side of the<br />
image is high side while the left is on the bottom. Additionally two holdup<br />
curves are shown, water (YWE) <strong>and</strong> gas (YGE). These holdups are also<br />
presented in the last track. This presentation allows quick method of<br />
determine fluid contacts <strong>and</strong> provide an accurate calculation of the fluid<br />
compositions.<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-21<br />
HAL9135
Features<br />
Makes both vertical <strong>and</strong> cross-sectional images available<br />
Valuable data can be obtained in deviated or horizontal<br />
wells when run in combination with traditional PL<br />
sensors. Running the SAT tool in combination allows a<br />
complete analysis regardless of well geometry<br />
Permits more accurate three-phase holdups<br />
Shows images in all types of stratified flow<br />
Has unsurpassed responses in both deviated <strong>and</strong><br />
horizontal wellbores<br />
Can produce video-like images of the fluid distribution<br />
across the borehole with further processing<br />
Length<br />
ft (m)<br />
4.63<br />
(1.4)<br />
FloImager ® Service Specifications<br />
Diameter<br />
in. (mm)<br />
1.69<br />
(42.9)<br />
Maximum Pressure<br />
psi (Mpa)<br />
15,000<br />
(103.4)<br />
Associated Answer <strong>Products</strong><br />
Production logging analysis (PLA)<br />
FloImager® 3D imaging product, CD-based 3D viewer<br />
Reliable water holdup measurements in highly deviated<br />
<strong>and</strong> horizontal wellbores<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
17.3<br />
(7.8)<br />
4-22 Cased-Hole <strong>Wireline</strong> <strong>Services</strong>
GHT Gas Holdup Tool<br />
Representing a major improvement over center sample<br />
production logging tools for horizontal <strong>and</strong> highly deviated<br />
wells, the GHT gas holdup tool is a unique tool that<br />
directly <strong>and</strong> accurately determines the volumetric fraction of<br />
gas over a cross-sectional volume element of the wellbore.<br />
This instrument operates in horizontal, highly deviated, <strong>and</strong><br />
vertical cased wells in any flow regime. It measures gas<br />
holdup directly <strong>and</strong> with greater accuracy using real-time<br />
downhole pressure <strong>and</strong> temperature, casing ID, <strong>and</strong> gas<br />
gravity measurements to generate a 0% to 100% gas holdup<br />
log in stratified or homogenized flows.<br />
The superior information provided by the GHT tool<br />
mitigates against the ambiguities that an interpreter of<br />
conventional production logs sometimes encounters.<br />
Applications<br />
Fast, accurate flow analysis<br />
Highly deviated horizontal <strong>and</strong> vertical cased wells<br />
Reservoir evaluation<br />
Features<br />
Determines gas holdup, independent of flow patterns or<br />
wellbore angles<br />
Provides an improved true fullbore measurement<br />
Helps identify water entry in gas wells<br />
Converts a complex three-phase flow analysis into a<br />
simple dual-phase analysis<br />
Improve underst<strong>and</strong>ing of actual downhole flow<br />
conditions in wells producing gas<br />
Real-time gas holdup measurements expedite the<br />
evaluation of well production<br />
Helps avoid costly errors in judgment based on<br />
inaccurate flow analysis<br />
Length<br />
ft (m)<br />
2<br />
(0.6)<br />
GHT Gas Holdup Tool Specifications<br />
Diameter<br />
in. (mm)<br />
1.687<br />
(42.8)<br />
GHT tool <strong>and</strong> data in a vertical low-velocity well with multiple flow<br />
patterns. Track 1 consists of gamma ray, temperature, <strong>and</strong> pressure. Since<br />
GHT data is corrected for PVT relationships, it is extremely important to<br />
have these temperature <strong>and</strong> pressure sensors run in combination with<br />
GHT tool. Tracks 2 <strong>and</strong> 3 show the wellbore diagram consisting of<br />
formation, cement, casing, <strong>and</strong> perforations. Track 4 highlights the<br />
comparison of calculated gas holdups between the fluid density tool <strong>and</strong><br />
the GHT tool. Track 5 shows the raw fluid density data. The raw GHT tool<br />
count rates are presented in Track 6. The last track provides the spinner<br />
data indicating fluid movement.<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-23<br />
HAL9226<br />
Maximum Pressure<br />
psi (Mpa)<br />
15,000<br />
(103.4)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
10.8<br />
(4.9)
MPL Memory Production Logging Tool<br />
MPL memory production logging is a system where<br />
slickline, conventional coiled tubing, or drillpipe conveyed<br />
tools acquire data without the need for electric line.<br />
The MPL system is comprised of the downhole data<br />
acquisition system, which includes memory production<br />
logging tools recording time-based data to the memory<br />
section. The st<strong>and</strong>ard memory section has 128 MB of<br />
memory <strong>and</strong> can be extended up to 1 GB of memory. It can<br />
run 62 tools at the same time. This new memory system can<br />
log production logging tools with casing or cement<br />
evaluation tools if required. It also includes the surface data<br />
acquisition system, comprising a depth <strong>and</strong> time recorder<br />
which records both time (from an internal clock) <strong>and</strong> depth<br />
pulses from a low current optical encoder. The unit can also<br />
be configured to record weight, tension, <strong>and</strong> other surface<br />
inputs. The Advanced Measurement System (AMS) can be<br />
included, comprising depth, time, weight, tension, <strong>and</strong><br />
casing collar locator recording <strong>and</strong> a job log. Some sample<br />
capacities are shown below.<br />
Time Interval<br />
sec/sample 8.0 MB 4.0 MB<br />
0.1 15 hours 7.5 hours<br />
0.5 70 hours 35 hours<br />
1.0 120 hours 60 hours<br />
Times given assume 6 PL tools <strong>and</strong> quartz pressure.<br />
Times are calculated to the nearest whole hour.<br />
Sample capacities might be limited by battery type.<br />
4 MB tool all 12 ch sampling at 1sec = 49.5 hours.<br />
Applications<br />
Downhole well problem diagnostics<br />
Production/injection profiles<br />
Treatment (stimulation) evaluation<br />
Multiple rate production logs<br />
Fall off tests<br />
Reservoir information<br />
Data for reservoir simulation<br />
This memory production log was obtained for an operator looking to cut<br />
high water production in a formation with a three-phase downhole flow<br />
regime. The MPL service captures logging data on a memory recorder.<br />
The data is equal in quality to data obtained with electric line services.<br />
Computing center analysis of the MPL data reveals that the bottom set<br />
of perforations is producing mostly water <strong>and</strong> only 2% of the total oil<br />
production <strong>and</strong> 6% of the gas. Remedial work to plug off the bottom zone<br />
should decrease water production <strong>and</strong> reduce water disposal costs without<br />
greatly affecting hydrocarbon production.<br />
4-24 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL964<br />
HAL965
Features<br />
Highly portable <strong>and</strong> easily deployed <strong>and</strong> can also be<br />
deployed on electric line if slickline is not available<br />
Utilizes the same conventional sensors as the st<strong>and</strong>ard<br />
electric line toolstring providing data of the same<br />
accuracy <strong>and</strong> resolution<br />
Can be deployed with coiled tubing in highly deviated or<br />
horizontal wells. Suitable for offshore locations where<br />
there are limitations in space, weight-lifting capacity, <strong>and</strong><br />
height restrictions<br />
PL Tool<br />
Category Tool Type<br />
Casing Collar<br />
Locator<br />
Correlation<br />
Flow<br />
Condition /<br />
Well<br />
Diagnostic<br />
Fluid<br />
Identification<br />
Production Gamma<br />
Ray<br />
Dual Caliper<br />
Quartz Pressure<br />
Gauge<br />
Fast Response<br />
Platinum Resistance<br />
Thermometer<br />
Inclinometer<br />
Accelerometer<br />
Enhanced<br />
Capacitance Water<br />
Holdup Tool<br />
Radioactive Fluid<br />
Density Tool<br />
Differential Pressure<br />
Fluid Density Tool<br />
Capacitance Array<br />
Tool<br />
Gas Holdup Tool<br />
Utilization of slickline simplifies the pressure control<br />
equipment<br />
Very high memory enabling combination of production<br />
logging tools with casing or cement evaluation tools like<br />
MIT/MTT or CBL/RCBL tools<br />
Associated Answer <strong>Products</strong><br />
Raw data hard copy log<br />
Production log analysis, an AFE analyzed hardcopy log<br />
MPL Memory Production Logging Tools Specifications Summary<br />
Tool<br />
Length<br />
in. (mm)<br />
18.5<br />
(470)<br />
Range of Measurement Resolution Accuracy<br />
23.1<br />
(586)<br />
37.5<br />
(953)<br />
19.01<br />
(483)<br />
12.5<br />
(318)<br />
10.7<br />
(272)<br />
26.2<br />
(665)<br />
22.9<br />
(582)<br />
51.9<br />
(1318)<br />
51.43<br />
(1306)<br />
24<br />
(610)<br />
Sensitivity<br />
Threshold<br />
20 keV approx.<br />
2 to 9 in. 0.015 in.<br />
0 to 15,000 psi<br />
50 to 350°F (10 to 177°C)<br />
0.008 psi <strong>and</strong><br />
PL Tool<br />
Category Tool Type<br />
Flowmeter<br />
Combination<br />
Tool<br />
Deployment<br />
Tools<br />
Inline Spinner<br />
Flowmeter<br />
Continuous Spinner<br />
Flowmeter (Bearing)<br />
Continuous Spinner<br />
Flowmeter (Jeweled)<br />
Caged Full Bore<br />
Flowmeter<br />
3 Arm<br />
Caged Full Bore<br />
Flowmeter<br />
6 Arm<br />
Diverter Flowmeter<br />
Spinner Array Tool<br />
Quartz Pressure<br />
CCL<br />
Capacitance /<br />
Temperature / Flow<br />
Head Tension Unit<br />
Roller Centralizer<br />
Spring Centralizer<br />
Swivel<br />
Knuckle Joints<br />
MPL Memory Production Logging Tools Specifications Summary<br />
Tool<br />
Length<br />
in. (mm) Range of Measurement Resolution Accuracy<br />
21<br />
(533)<br />
9<br />
(229)<br />
34.9<br />
(886)<br />
34.9<br />
(886)<br />
70.7<br />
(1796)<br />
46<br />
(1168)<br />
19.01<br />
(483)<br />
Approx.<br />
18.5<br />
(470)<br />
w/o flow<br />
mech<br />
section<br />
22.8<br />
(580)<br />
Max fluid velocity 3,450 ft/min<br />
Max fluid velocity 2,000 ft/min<br />
Max fluid velocity 3,450 ft/min<br />
500 ft/min (2.54 m/s), 28,250 BPD<br />
in 7-in. casing; with solid shaft tool<br />
can work up to 1,200 ft/min<br />
500 ft/min (2.54 m/s), 28,250 BPD<br />
in 7-in. casing; with solid shaft tool<br />
can work up to 1,200 ft/min<br />
Minimum 6-8 m 3 per day. Maximum<br />
approx. 400 m 3 /d (6 psi drop<br />
~120 lb uplift in 5 1/2-in. casing)<br />
3 1/2 to 7-in. casing<br />
Threshold<br />
approx 8 ft/min<br />
in water<br />
Threshold<br />
approx 5 ft/min<br />
in water<br />
Threshold<br />
approx 5 ft/min<br />
in water<br />
1.7 ft/min approx<br />
(0.01m/s),<br />
100 BPD in 7-in.<br />
casing<br />
1.7 ft/min approx<br />
(0.01m/s),<br />
100 BPD in<br />
7-in. casing<br />
Threshold<br />
approx 8 ft/min<br />
in water<br />
12 ft/min in<br />
water<br />
Same as quartz pressure gauge <strong>and</strong> CCL individual tools<br />
10 pulses/rev<br />
10 pulses/rev<br />
10 pulses/rev<br />
10 pulses/rev<br />
10 pulses/rev<br />
10 pulses/rev<br />
3/8-in. spinner<br />
3 pulses/rev<br />
Same as capacitance / temperature flow individual tool. Flowmeter<br />
mechanical section can be any type of continuous or full bore flowmeter.<br />
-400 kg (compr.) to +1000 kg<br />
Hysteresis<br />
5% FS<br />
Temperature<br />
Drift 5% FS<br />
4-26 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
10.6<br />
(4.8)<br />
3.5<br />
(1.6)<br />
mechanical<br />
section only<br />
3.5<br />
(1.6)<br />
mechanical<br />
section only<br />
10<br />
(4.5)<br />
10<br />
(4.5)<br />
Approx 15<br />
(6.8)<br />
8.8<br />
(4.0)<br />
Approx 5.4<br />
(2.5)<br />
w/o flow<br />
mech section<br />
10<br />
(4.5)<br />
Spinner shroud<br />
OD 1 11/16,<br />
2 1/8, 3 1/8 in.<br />
Spinner shroud<br />
OD 1 11/16,<br />
2 1/8, 3 1/8 in.<br />
Spinner shroud<br />
OD 1 11/16,<br />
2 1/8, 3 1/8 in.<br />
Available for<br />
different casing<br />
size<br />
4 1/2 to 9 5/8 in.<br />
(114 to 244 mm)<br />
Available for<br />
different casing<br />
size<br />
4 1/2 to 9 5/8 in.<br />
(114 to 244 mm)<br />
3 1/2 to 9 5/8 in.<br />
(90 to 244 mm)<br />
6 miniature<br />
spinner equispaced<br />
around<br />
circumference<br />
Repeatability<br />
±2% FS<br />
Different roller centralizers are available with 3 or 4 arms with single or double rollers in each arm. Also have different<br />
centralization force as per operational requirement. Approx Length - 33.25 in. (845 mm) <strong>and</strong> weight around 12 lb.<br />
Different compact spring bows are available with 3 to 6 springs. Also have different centralization force as per<br />
operational requirement. Approx Length - 28 in. (711 mm) <strong>and</strong> weight around 10 lb.<br />
This is a monoconductor swivel joint which allows free rotation between the upper <strong>and</strong> lower heads while maintaining<br />
electrical continuity through the tool. Different sizes available, Approx Length - 11 in. (280 mm) <strong>and</strong> weight 4 lb.<br />
7<br />
(178)<br />
Ball type knuckle for deployment in<br />
deviated well<br />
Weight<br />
lb (kg) Others<br />
1. Tools specified have nominal OD of 1 1//16 in. Tools with OD of 1 3/8 in. are also available.<br />
2. All tools have maximum pressure rating of 15,000 psi <strong>and</strong> maximum temperature rating of 350°F or 177°C. For higher pressure or higher temperature tools<br />
contact your local <strong>Halliburton</strong> representative.<br />
3. Telemetry is very high speed capable of running 62 tools in combination (virtually no limit on tool combination for telemetry).<br />
3.5<br />
(1.6)
Quartz Pressure Tool<br />
For high-precision downhole pressure measurement,<br />
<strong>Halliburton</strong> offers a quartz gauge tool that employs<br />
quartzdyne transducers, an industry st<strong>and</strong>ard quartz crystal<br />
pressure sensor. The tool provides both pressure <strong>and</strong> gauge<br />
temperature outputs.<br />
Fluid pressure applied to the quartz tension member changes<br />
the resonant frequency of the quartz crystal. Thermal<br />
compensation of the sensor <strong>and</strong> measurement of its<br />
temperature allows the calculation of very accurate, highresolution<br />
downhole pressures.<br />
Applications<br />
Measuring shut-in <strong>and</strong> flowing pressures at prescribed<br />
depth levels<br />
Diagnosing well problems<br />
Features<br />
Detects minimum pressure changes <strong>and</strong> temperature<br />
variations<br />
Conveyance flexibility with the following methods:<br />
slickline, wireline, coiled tubing, <strong>and</strong> drillpipe<br />
Resistance to corrosion<br />
Associated Answer <strong>Products</strong><br />
Plots that are available at the wellsite include flowing<br />
pressure surveys, static pressure gradient surveys, log-log<br />
pressure buildup, <strong>and</strong> derivative pressure plots<br />
Advanced pressure transient analysis can also be done<br />
utilizing Sapphire software<br />
Section<br />
Memory<br />
SRO<br />
Length<br />
ft (m)<br />
1.0<br />
(0.3)<br />
1.9<br />
(0.59)<br />
Quartz Pressure Tool Specifications<br />
Diameter<br />
in. (mm)<br />
1.65<br />
(42)<br />
1.65<br />
(42)<br />
This log example shows how the quartz pressure tool can help determine<br />
flowing conditions. Track 1 shows the gamma ray (GR1) <strong>and</strong> four collar<br />
locator logs (CCL1-4) showing depth correlation. Track 2 provides four<br />
quartz pressure readings from continuous passes in this horizontal well.<br />
Normally in a stabilized well, the pressures have a common gradient as<br />
shown in Pass 4. Pass 1 <strong>and</strong> 2 indicate that this well has not been stabilized<br />
after shut-in. Track 3 has the four temperature passes with both fluid<br />
entry (higher temperatures) <strong>and</strong> gas entry (lower temperatures) in Pass 1.<br />
Track 4 includes some of the results from the CAT tool that can be used<br />
to determine fluid holdups.<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-27<br />
HAL9250<br />
Maximum Pressure<br />
psi (Mpa)<br />
15,000<br />
(103.4)<br />
15,000<br />
(103.4)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
6.5<br />
(2.95)<br />
9.6<br />
(4.35)
Casing <strong>and</strong> Tubing Evaluation<br />
MAC Multi-Arm Caliper Tool<br />
<strong>Halliburton</strong> offers a wide variety of multi-arm calipers that<br />
provide high-resolution details about the condition of the<br />
casing or tubing, including accurate measurements of its<br />
internal radius. The MAC tool is available for most casing<br />
<strong>and</strong> tubing sizes. The tool can operate 24 to 80 arms <strong>and</strong> is<br />
deployed on wireline, slickline, or coiled tubing. All data<br />
collected is used to generate 3D images of the casing or<br />
tubing.<br />
Applications<br />
Detail the condition of casing or tubing with accurate<br />
internal radius measurements<br />
3D images of casing or tubing<br />
Features<br />
Comes in several sizes to work in a wide range of casing<br />
Can be deployed on wireline, slickline, or coiled tubing<br />
Can obtain data in horizontal wells<br />
Can be combined with production logging or cement<br />
bond tool<br />
Accurately identifies casing damage such as holes, splits,<br />
or cracks <strong>and</strong> their depth in the wellbore<br />
Can be used for scale evaluation<br />
Provides a method for mapping perforations<br />
Associated Answer <strong>Products</strong><br />
MITview (multifinger imaging tool presentation<br />
package)<br />
MITpro (multifinger imaging tool software)<br />
Number<br />
of Arms<br />
24<br />
40<br />
60<br />
80<br />
Length<br />
ft (m)<br />
3.75<br />
(1.1)<br />
5.5<br />
(1.7)<br />
5.75<br />
(1.8)<br />
3.33<br />
(1.0)<br />
MAC Multi-Arm Caliper Specifications<br />
Diameter<br />
in. (mm)<br />
1.69<br />
(42.9)<br />
2.75<br />
(69.9)<br />
4.00<br />
(101.6)<br />
8.00<br />
(203.2)<br />
This 3D view shows an enlarged OD caused by perforating the well.<br />
This 3D image shows general deep corrosion with light deposits in the<br />
body possibly caused from cable movement.<br />
4-28 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL10363<br />
HAL10364<br />
Maximum Pressure<br />
psi (Mpa)<br />
15,000<br />
(103.4)<br />
15,000<br />
(103.4)<br />
15,000<br />
(103.4)<br />
15,000<br />
(103.4)<br />
Maximum Temperature<br />
°F (°C)<br />
150<br />
(65.6)<br />
150<br />
(65.6)<br />
150<br />
(65.6)<br />
150<br />
(65.6)<br />
Weight<br />
lb (kg)<br />
20<br />
(9.1)<br />
62<br />
(28.1)<br />
100<br />
(45.4)<br />
93<br />
(42.2)
CAST-V Circumferential Acoustic Scanning Tool-Visualization<br />
The CAST-V tool is an ultrasonic tool that provides highresolution<br />
images in both open <strong>and</strong> cased holes. The tool’s<br />
interchangeable head rotates a full 360° <strong>and</strong> contains a highfrequency<br />
acoustic transducer to provide a full 360° profile of<br />
the borehole or cement. A second acoustic transducer is<br />
mounted in the tool housing <strong>and</strong> is used to measure<br />
characteristics of the borehole fluid. A directional sub is<br />
provided to orient images to either the high side of the hole<br />
or to north. The image mode, run primarily in open hole,<br />
consists of 200 points horizontally by 40 samples per foot<br />
vertically while the cased-hole mode measures 100 points by<br />
4 samples/ft. The CAST-V tool is designed to operate in<br />
conjunction with other DITS tools.<br />
The system provides high-resolution images indicating<br />
texture changes in the borehole wall or on the interior<br />
portion of the casing. These images can be used to identify<br />
fractures in the formation or slight internal defects in casing.<br />
The CAST-V tool in the cased-hole mode also determines the<br />
casing thickness for pipe inspection. Simultaneously the<br />
CAST-V tool determines the type of material in the annular<br />
space between the casing <strong>and</strong> borehole wall.<br />
The CAST-V tool must be run centralized in fluid filled<br />
boreholes. It must be the bottom tool in any combination. Its<br />
operation is limited by factors such as high mud density <strong>and</strong><br />
dissolved gases that increase the attenuation of the tool’s<br />
acoustic pulses as they travel through the borehole fluid.<br />
CAST-V tool differs from other ultrasonic type tools in the<br />
cased-hole mode by several different ways. It has 100 shots<br />
per depth frame versus 72 (maximum) <strong>and</strong> includes a realtime<br />
fluid travel time (FTT) measurement. The competition<br />
down logs FTT <strong>and</strong> then plugs the results into the uplog. All<br />
measurements are made real-time with no mode selection to<br />
determine what is or what is not being processed. It is fully<br />
combinable with all DITS tools, especially the M305 FWS<br />
tool for the CBL portion. The complete navigation package is<br />
st<strong>and</strong>ard with service. The competitor’s st<strong>and</strong>ard service does<br />
not include a navigation package—they additionally charge<br />
for running the service.<br />
Applications<br />
Simultaneous ultrasonic pipe inspection <strong>and</strong> cement<br />
evaluation<br />
2D <strong>and</strong> 3D borehole imaging<br />
Process images, histograms, <strong>and</strong> curve-type data<br />
HAL9227<br />
The casing-evaluation presentation includes casing ovality, eccentricity,<br />
hole deviation, <strong>and</strong> gamma ray in Track 1. In this instance, the eccentricity<br />
is composed of both tool <strong>and</strong> casing eccentricity due to formation<br />
movement. Track 2 shows a cross-sectional presentation of the pipe shape.<br />
A cross-sectional of the pipe wall is presented in Track 3. Track 4 provides<br />
the average, minimum, <strong>and</strong> maximum value of the pipe radius that is<br />
shown in Track 5. Track 6 provides the average, minimum, <strong>and</strong> maximum<br />
value of the pipe thickness that is the image plotted in last Track 7. On the<br />
image logs red shows pipe thinning while blue indicates pipe thickening.<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-29
Features<br />
Allows 100 shots per depth frame measurement,<br />
providing complete circumferential coverage in casedhole<br />
cement evaluation <strong>and</strong> pipe inspection<br />
Near real-time evaluation of complex <strong>and</strong> lightweight<br />
cements is accomplished through ACE processing<br />
Combinable with all DITS tools. This can reduce<br />
rigtime when run with the M305 FWS tool for the<br />
cement bond log<br />
Simultaneous cement evaluation <strong>and</strong> casing inspection<br />
capability<br />
Real-time fluid cell measures both borehole fluid transit<br />
time <strong>and</strong> fluid impedance for measured data correction<br />
Real-time casing thickness, casing OD, <strong>and</strong> ID<br />
Associated Answer <strong>Products</strong><br />
ACE processing for cement evaluation<br />
CASE evaluation for casing inspection<br />
The CAST-V tool is also useful in cement evaluation. See<br />
page 33 for more information on Cement Evaluation tools.<br />
The cement-evaluation presentation includes casing ovality <strong>and</strong> tool<br />
eccentricity in Track 1 along with the gamma ray. Conventional CBL<br />
amplitude <strong>and</strong> amplified amplitude data is presented in Track 2. Track 3<br />
provides the typical CBL waveform showing both pipe to cement bond<br />
along with cement to formation bond. Data from the CAST-V scanner<br />
is displayed in Tracks 4 <strong>and</strong> 5. Track 4 provides information regarding the<br />
average impedance of the ZP image in Track 5. Likewise a CBI is a bond<br />
index from the same image <strong>and</strong> provides a quick indication of the percent<br />
of bond. The image in Track 5 is the Z map from 0 to 360° (left to right)<br />
with 0° representing the high side of the hole. The center of the track is<br />
scaled at 180°, which represents the low side of the hole.<br />
CAST-V Circumferential Acoustic Scanning Tool-Visualization Specifications<br />
Length<br />
ft (m)<br />
17.9<br />
(5.5)<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
4-30 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL9230<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
316<br />
(143.3)
The FASTCAST Fast Circumferential Acoustic Scanning Tool<br />
The FASTCAST tool provides the same industry leading<br />
measurements <strong>and</strong> products for cement evaluation or pipe<br />
inspection as the CAST-V tool but at speeds up to five<br />
times faster.<br />
The FASTCAST tool data acquisition system is versatile <strong>and</strong><br />
programmable at the wellsite, fully optimized for speed,<br />
based on the customer’s requirements <strong>and</strong> on the<br />
characteristics of the borehole.<br />
With a resolution improved by at the most a factor of 12 in<br />
pipe inspection mode, the FASTCAST tool can provide 100%<br />
coverage of casings up to 20-in. in diameter.<br />
The FASTCAST tool provides true measured full coverage<br />
unavailable by most other acoustic, electric, or mechanical<br />
devices.<br />
The factors that influence the logging speed are:<br />
Horizontal coverage<br />
Borehole size – smaller holes are logged faster because<br />
they require less shots / scan for the same amount of<br />
horizontal coverage<br />
Vertical resolutions – lower resolution implying higher<br />
speed<br />
In open hole, the FASTCAST tool provides complete<br />
borehole imaging for accurate, precise, formation evaluation.<br />
In cased-hole, ultrasonic pipe inspection <strong>and</strong> cement<br />
evaluation can be obtained simultaneously.<br />
The FASTCAST tool in cement evaluation mode is used<br />
primarily to determine cement bonding <strong>and</strong> image channels<br />
in cement directly behind casing, but it can also be used to<br />
measure casing characteristics such as thickness <strong>and</strong> internal<br />
<strong>and</strong> external diameters. Images can be oriented to either tool<br />
body or the high side of the hole in any operating mode.<br />
When combined with a CBL tool, the cement evaluation log<br />
can be acquired at 60 ft/min or twice as fast as previous<br />
generation tools, yet providing the same quality product as<br />
the CAST-V tool for all cement types, including foam,<br />
through the <strong>Halliburton</strong> proprietary ACE processing. This<br />
increased logging speed results in a significant reduction in<br />
operating cost to the operator through minimized<br />
unproductive rig time.<br />
The FASTCAST tool in pipe inspection mode is optimized to<br />
provide the hole coverage suited to the application. The<br />
vertical resolution can be the traditional 3 in. but can be<br />
refined down to 0.1 in. Similarly, the number of waveforms<br />
per scan can be adjusted to provide full horizontal coverage<br />
down to the beam footprint of 0.25 in. The optimum<br />
coverage being identified, the job planner allows the engineer<br />
to acquire the data at the maximum logging speed suited for<br />
the application.<br />
Other features that open a wide range of new possibilities for<br />
looking at details further away from the casing / cement<br />
interface are the user-configurable waveform length <strong>and</strong><br />
sampling interval.<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-31<br />
HAL17810
Casing<br />
OD in.<br />
The FASTCAST Tool Specifications<br />
Casing Data CAST-V The FASTCAST Tool Logging Speed (ft/min)<br />
Casing Weight<br />
lb / ft<br />
With or Without<br />
CBL,<br />
100 shots / scan,<br />
4 spf<br />
St<strong>and</strong>alone, Full<br />
Horizontal Coverage<br />
(4 spf)<br />
With CBL <strong>and</strong> Full<br />
Horizontal<br />
Coverage (4 spf)<br />
St<strong>and</strong>alone, Full<br />
Horizontal <strong>and</strong> Vertical<br />
Coverage (12 spf)<br />
5.500 17 32 123 60 41<br />
6.000 20 32 123 60 41<br />
7.000 29 30 103 60 34<br />
9.625 43 24 82 60 27<br />
13.375 68 15 55 43 18<br />
18.625 106 9 45 45 15<br />
Temperature<br />
°F (°C)<br />
350<br />
(175)<br />
Pressure<br />
psi (kPa)<br />
20,000<br />
(137 900)<br />
*With interchangeable transducer head<br />
Tool OD<br />
in. (mm)<br />
3.625<br />
(92)<br />
Length<br />
in. (m)<br />
215<br />
(5.46)<br />
Weight<br />
lb (kg)<br />
316<br />
(143)<br />
Min Hole ID<br />
in. (mm)<br />
Max Hole ID*<br />
in. (mm)<br />
Vertical<br />
sampling<br />
in.<br />
Logging<br />
speed<br />
ft/min<br />
4-32 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
4.25<br />
(108)<br />
22.00<br />
(559) 0.1 to 3.0 60 typical
Cement Evaluation<br />
Cement Bond Log (CBL)<br />
Cement bond tools (CBT) are sonic logging tools that have<br />
one omni-directional transmitter <strong>and</strong> two omni-directional<br />
receivers. Cement bond log tools are used to evaluate the<br />
effectiveness of cementing operations.<br />
The transit time measurement of the acoustic signal at the<br />
3-ft receiver is used for two purposes: verification of the<br />
centralization of the CBL in free, non-bonded casing; <strong>and</strong> to<br />
identify fast formations in acoustically bonded intervals. In<br />
other than fast formations or free pipe, the transit time<br />
measurement is undefined.<br />
Correlation of the waveform data with other petrophysical<br />
measurements, such as gamma ray, porosity, or resistivity<br />
data, are used to identify the acoustic coupling of the cement<br />
to both the casing <strong>and</strong> formation. ACE advanced waveform<br />
processing methods can be used for concentric casing string<br />
evaluation.<br />
Cement bond logging tools come in a number of different<br />
tool diameters, pressure, <strong>and</strong> temperature ratings. Small<br />
diameter CBL tools are available for both through-tubing<br />
logging operations <strong>and</strong> small diameter casing completions.<br />
Applications<br />
Measuring the attenuation of the acoustic energy in the<br />
casing-to-cement interface<br />
Evaluating the cement-to-formation coupling by the<br />
correlation of the waveform data to other petrophysical<br />
measurements<br />
Indicating channels or intervals with only a partial bond<br />
Locating free pipe <strong>and</strong> top of cement<br />
Evaluating the mud displacement processes<br />
This log example illustrates nearly free pipe, an apparent top of cement<br />
around X80, <strong>and</strong> below Y26 it is well bonded. Track 1 consists of the<br />
gamma ray for correlation <strong>and</strong> travel time which is used for quality<br />
control. Track 2 consists of the amplitude curve <strong>and</strong> amplified amplitude<br />
which indicates cement to casing bond. Track 3 consists of the CBL<br />
waveform which indicates both casing to cement bond along with<br />
cement to formation bond. Straight lines in the CBL waveform along<br />
with high amplitude readings indicate poor cement to casing bond.<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-33<br />
HAL9231
Features<br />
Runs in combination with a gamma ray <strong>and</strong> a collar<br />
locator for depth correlation purposes<br />
Optional neutron correlation logs can be used in<br />
formations where there is minimal gamma ray contrast<br />
Digital telemetry versions are combinable with the<br />
CAST-V tool for simultaneous ultrasonic cement <strong>and</strong><br />
casing evaluation<br />
CBL tools are available that can be run on all types of<br />
wireline from large diameter 0.9375-in. slammer heptacables<br />
to 0.22-in. sour gas service monoconductor cables<br />
Sonde<br />
FWST-A<br />
Full Wave Sonic Tool<br />
HFWS-A Hostile Full<br />
Wave Sonic Tool<br />
*6 hour<br />
Length<br />
ft (m)<br />
20.4<br />
(6.2)<br />
30.2<br />
(9.2)<br />
Cement Bond Log (CBL) Specifications<br />
Diameter<br />
in. (mm)<br />
3.63<br />
(92.2)<br />
2.75<br />
(69.9)<br />
Cement sheath evaluation in a wide range of casing sizes<br />
from small diameter tubing to over 20-in. casing<br />
Accurate correlation to open-hole measurements<br />
Digital recording of the waveform data for real-time data<br />
transmission <strong>and</strong> advanced interpretational methods<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
25,000<br />
(172.4)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
500*<br />
(260.0)<br />
Weight<br />
lb (kg)<br />
365<br />
(165.6)<br />
340<br />
(154.2)<br />
4-34 Cased-Hole <strong>Wireline</strong> <strong>Services</strong>
Radial Cement Bond Tools<br />
Cement bond tools (CBT) are sonic logging tools that have<br />
one omni-directional transmitter <strong>and</strong> two omni-directional<br />
receivers. In addition, the radial cement bond log (RCBL)<br />
tool has eight radial receivers <strong>and</strong> the RCBS tool has six.<br />
Radial cement bond tools are used to evaluate the<br />
effectiveness of cementing operations.<br />
The transit time measurement of the acoustic signal at the<br />
3-ft receiver is used for two purposes—to verify the<br />
centralization of the radial cement bond tool in free, nonbonded<br />
casing, <strong>and</strong> to identify fast formations in acoustically<br />
bonded intervals. In other than fast formations or free pipe,<br />
the transit time measurement is undefined.<br />
Correlation of the waveform data with other petrophysical<br />
measurements, such as gamma ray, porosity, or resistivity<br />
data is used to identify the acoustic coupling of the cement to<br />
both the casing <strong>and</strong> formation. ACE advanced waveform<br />
processing methods can be used for concentric casing string<br />
evaluation.<br />
Applications<br />
Indicating channels or intervals using radial receivers<br />
Measuring the attenuation of the acoustic energy in the<br />
casing to cement interface<br />
Evaluating the cement to formation coupling by the<br />
correlation of the waveform data to other petrophysical<br />
measurements<br />
Locating free pipe <strong>and</strong> top of cement<br />
Evaluating the mud displacement processes<br />
Results from a specially designed test well for the RCBL <strong>and</strong> RCBS tools.<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-35<br />
HAL9232
Features<br />
It runs in combination with a gamma ray <strong>and</strong> a collar<br />
locator for depth correlation purposes<br />
Optional neutron correlation logs or DSN dual-spaced<br />
neutron tool logs can be used in formations where there<br />
is minimal gamma ray contrast<br />
DSN tool can be run for formation evaluation<br />
It can be run on all types of wireline from large diameter<br />
0.9375-in. slammer hepta-cables to 0.22-in. sour gas<br />
service monoconductor cables<br />
Sonde<br />
RCBS<br />
RCBS-P1<br />
RCBS-P2<br />
RCBL<br />
HTHP*<br />
Length<br />
ft (m)<br />
15<br />
(4.57)<br />
13.12<br />
(4)<br />
8.75<br />
(2.68)<br />
13.83<br />
(4.23)<br />
13.175<br />
(4.2)<br />
With<br />
Centralizers<br />
ft (m)<br />
21.6<br />
(6.58)<br />
17.72<br />
(5.4)<br />
13.15<br />
(4)<br />
20.43<br />
(6.23)<br />
Radial Cement Bond Tool Specifications<br />
OD<br />
in. (cm)<br />
1.69<br />
(4.29)<br />
1.69<br />
(4.29)<br />
2.75<br />
(6.98)<br />
3.125<br />
(7.94)<br />
3.125<br />
(7.94)<br />
Maximum<br />
Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
20,000<br />
(137.9)<br />
30,000<br />
(206.8X)<br />
Maximum<br />
Temperature<br />
°F (°C)<br />
350<br />
(176.68)<br />
450<br />
(232)<br />
350<br />
(176.68)<br />
375<br />
(190)<br />
400<br />
(204.4)<br />
Cement sheath evaluation in a wide range of tubing or<br />
casing sizes from small diameter tubing to 13.38-in.<br />
casing, including channel identification<br />
Accurate correlation to open-hole measurements<br />
Digital recording of the waveform data for real-time data<br />
transmission <strong>and</strong> advanced interpretational methods<br />
Weight<br />
lb (kg)<br />
75<br />
(34)<br />
78<br />
(35.38)<br />
106.5<br />
(48.31)<br />
215<br />
(97.5)<br />
151.65<br />
(68.79)<br />
*Supplies are limited. Please contact your local <strong>Halliburton</strong> representative for more information.<br />
Maximum<br />
Casing<br />
in. (cm)<br />
7.5<br />
(19)<br />
7<br />
(17.78)<br />
9.625<br />
(24.45)<br />
13.38<br />
(33.98)<br />
13.4<br />
(34)<br />
Minimum<br />
Casing<br />
in. (cm)<br />
2<br />
(5.1)<br />
2.875<br />
(7.3)<br />
4<br />
(10.16)<br />
3.75<br />
(9.53)<br />
3.75<br />
(9.53)<br />
Borehole Fluids<br />
Salt Fresh Oil Air<br />
X X X<br />
X X X<br />
X X X<br />
X X X<br />
X X X<br />
4-36 Cased-Hole <strong>Wireline</strong> <strong>Services</strong>
ACE Advanced Cement Evaluation Process<br />
The ACE advanced cement evaluation process helps<br />
provide quick, accurate information concerning cement<br />
bond for all st<strong>and</strong>ard logging tools <strong>and</strong> procedures for any<br />
type of cement mixtures, including foam, latex, <strong>and</strong> other<br />
complex slurries.<br />
Traditional cement sheath interpretation, using the st<strong>and</strong>ard<br />
cement bond log (CBL) or any other cement evaluation tool<br />
has severe limitations when used to evaluate complex<br />
cements. Lightweight, foamed, or complex cements affect the<br />
traditional methods of determining zonal isolation, which<br />
may create the misleading impression that the cement bond<br />
is inadequate. This can lead to the ordering of expensive <strong>and</strong><br />
completely unnecessary remedial cementing.<br />
The ACE process is a new way of interpreting the cement<br />
evaluation tool data that is already being recorded during the<br />
logging runs. Although the ACE process was originally<br />
developed for lightweight cements, experience <strong>and</strong><br />
experiments have shown that it provides a superior method<br />
for interpreting any type of cement. Above all it gives clear<br />
answers to the most urgent questions:<br />
How good is my zonal isolation?<br />
Do I need a squeeze job?<br />
The ACE process yields its greatest benefit when evaluating<br />
both the cement to pipe bond <strong>and</strong> the cement to formation<br />
bond. To properly evaluate the cement to casing bond, the<br />
FASTCAST <strong>and</strong> CAST-V ultrasonic tools along with the<br />
ACE process provide the best solution. However, both<br />
segmented <strong>and</strong> radial bond tools can be evaluated with the<br />
ACE process <strong>and</strong> still provide excellent information<br />
regarding the cement to pipe bond.<br />
The CBL <strong>and</strong> other sonic tools are used to determine the<br />
cement to formation bond along with the cement to casing<br />
bond. The ACE process uses the sonic waveforms to<br />
highlight the differences between bonded, partially bonded,<br />
micro-annulus, <strong>and</strong> free pipe. The ACE process can help<br />
determine the presence of cement between two casing<br />
strings, which was extremely difficult to quantify with<br />
previous logs <strong>and</strong>/or interpretation procedures.<br />
These extraordinary results are the product of a new<br />
technique based on a statistical-variation process to<br />
distinguish cement from fluid, even when both have the same<br />
raw value. This process actually will use two different<br />
methods to determine zonal isolation—the original tool data<br />
<strong>and</strong> the activity level of the data. Through this process, the<br />
activity level is determined <strong>and</strong> will allow easy differentiation<br />
between solids <strong>and</strong> fluids. In addition, new bond-index<br />
curves <strong>and</strong> special log presentations have been developed to<br />
make interpretation quick <strong>and</strong> unambiguous.<br />
The ACE process works on every cement evaluation tool that<br />
<strong>Halliburton</strong> offers as well as effectively evaluating data from<br />
other service companies. Not only does this method work on<br />
data from both the rotating (FASTCAST, CAST-V tools),<br />
<strong>and</strong>/or stationary ultrasonic logs (PET tool), it also provides<br />
detailed information using st<strong>and</strong>ard CBL logs, sonic logs,<br />
dipole sonics, segmented bond logs, <strong>and</strong> the newer<br />
generation of radial bond logs (RBT).<br />
ACE analysis has been proven effective on cementing jobs in<br />
all parts of the world <strong>and</strong> on every type of cement now in use.<br />
It saves time <strong>and</strong> money by eliminating countless<br />
unnecessary squeeze jobs <strong>and</strong> associated expenses. Reducing<br />
the amount of unnecessary remedial cement operations will<br />
allow the customer to reduce operational expenses <strong>and</strong><br />
contribute to the bottom line.<br />
Features<br />
Uses every cement evaluation tool to provide detailed<br />
information about cement bond<br />
Works with existing logging procedures<br />
Enhances current logs to achieve a better underst<strong>and</strong>ing<br />
of zonal isolation<br />
Delivers a reliable cement bond index<br />
Works for any cement—conventional, complex,<br />
lightweight, or foam<br />
Helps improve cement interpretation for multiple casing<br />
strings<br />
Delivers answers in minutes on location, using your log<br />
or data tape<br />
Helps provide accurate <strong>and</strong> dependable cement bond<br />
interpretation regardless of the service company<br />
Saves time <strong>and</strong> money by helping eliminate countless<br />
unnecessary squeeze jobs <strong>and</strong> associated expenses<br />
Reduces the customer’s operational expenses <strong>and</strong><br />
contributes to the bottom line by helping to eliminate<br />
unnecessary remedial cement operations<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-37
Track 1 presents correlation data (GR), quality control (ECTY), <strong>and</strong> the average impedance (ZAVG) which provides a<br />
quick interpretation of the cement placement. Track 2 presents the amplitude (AMP), amplified amplitude (AAMP),<br />
filtered cement bond index (FCBI), as well as the computed cement bond index (FCEMBI). Track 3 contains a st<strong>and</strong>ard<br />
CBL waveform display (WMSG). Track 4 is the total CBL waveform (WMSGT) which is the ACE processing which<br />
highlights the collar response. The ultrasonic impedance map (ZP) is presented in Track 5, which indicates the impedance<br />
of the material behind pipe. Track 6 (DZ) is the variance of the impedance map which highlights the differences between<br />
solids (cement) <strong>and</strong> liquids. Track 7 (CEMT) shows the result of both the impedance <strong>and</strong> variance in determination of<br />
solids vs. fluids. Fluids are designated as blue, while cement is indicated by the brown color. Tracks 8 to 16 provide 5<br />
segmented curves from the impedance image broken into 9 segments around the wellbore. High activity indicates solids,<br />
<strong>and</strong> low activity indicates fluid. In the zone F notice how the curves have both low impedance <strong>and</strong> low activity compared<br />
to the data immediately above it in zone C.<br />
4-38 Cased-Hole <strong>Wireline</strong> <strong>Services</strong>
Mechanical <strong>Services</strong><br />
Pipe Recovery<br />
Chemical Cutter<br />
Chemical cutters eject a circular stream<br />
of bromine trifluoride (BrF 3) to<br />
dissolve pipe with a clean cut that leaves<br />
no debris <strong>and</strong> does not require milling<br />
prior to pipe retrieval. Built-in<br />
flexibility allows the tool to be adapted<br />
for many special cutting applications<br />
where other cutting methods may be<br />
ineffective or undesirable.<br />
Chemical cutters provide a clean pipe<br />
cut. Chemical cutters can also shorten<br />
operating time <strong>and</strong> reduce rig costs by<br />
eliminating the flare associated with<br />
explosive cutters <strong>and</strong> the related need to<br />
dress flares with a mill run before<br />
fishing operations can start.<br />
Additionally, chemical cutters can be<br />
used to release specially designed<br />
permanent packers such as<br />
<strong>Halliburton</strong>’s AHR cut-to-release<br />
packer. They can be used to cut pipe<br />
<strong>and</strong> casing during plug <strong>and</strong><br />
ab<strong>and</strong>onment operations, sever duplex-<br />
22 nickel/chromium tubing or other<br />
high-grade tubulars for salvage or<br />
reuse, <strong>and</strong> replace or retrieve old or<br />
deteriorating pipe in environmentally<br />
sensitive areas.<br />
Applications<br />
Re-establishing circulation during<br />
drilling operations by chemically<br />
punching drill collars or heavy<br />
weight pipe<br />
Removing metal restrictions<br />
blocking the well in open or cased<br />
holes with downward chemical junk<br />
shot<br />
Cutting drillpipe after freepoint <strong>and</strong><br />
backoff operations when sensitive<br />
washover <strong>and</strong> fishing operations are<br />
anticipated<br />
Cutting large pipe (7-in. or larger<br />
OD) utilizing a special wagon wheel<br />
configuration<br />
Using chemical cutter/tubing<br />
hanger combination in high<br />
pressure situations when normal<br />
operations may cause pipe to drop<br />
after being cut<br />
Cutting st<strong>and</strong>ard-diameter pipe<br />
through normal restrictions<br />
Shooting large holes in tubulars for<br />
gravel pack production<br />
Chemical cutters require the following<br />
inputs or samples to perform properly:<br />
Well sketch<br />
Type of pipe to be cut (ID, OD,<br />
metal composition, any plastic<br />
coatings)<br />
Any other restrictions or problems<br />
Temperature <strong>and</strong> pressure at cutting<br />
depth<br />
Type of fluid in the well, including<br />
any solvents or paraffins in the well<br />
Any other ID restrictions above the<br />
depth to be cut<br />
Features<br />
St<strong>and</strong>ard cutting head sizes from<br />
0.75-in. to 5.5-in. OD<br />
Unique holddown system to<br />
centralize the tool for even cuts<br />
without damaging pipe<br />
Deployment via electric wireline,<br />
coiled tubing, rigid tubing, or<br />
slickline<br />
Can pass through normal<br />
restrictions <strong>and</strong> still make a clean<br />
cut on st<strong>and</strong>ard size tubulars below<br />
the restriction<br />
Performs under a wide range of<br />
temperatures, pressures, <strong>and</strong> depths<br />
Produces no debris or drillpipe<br />
deformation which might require<br />
milling<br />
Does not damage adjacent string<br />
during cutting<br />
Severs pipe flare-free for retrieval<br />
through a packer or other<br />
restriction<br />
Does not change ID or OD of the<br />
cut<br />
Capable of cutting high-grade<br />
tubulars<br />
Specially designed slip assembly<br />
maintains mechanical tool stability<br />
<strong>and</strong> helps ensure that pieces of<br />
metal are not ejected from the tool<br />
in case of accidental firing<br />
Manufacture from high-grade, heat<br />
treated steel that will not rupture<br />
even if tool is accidentally fired at<br />
the surface<br />
Unique safety sleeve that virtually<br />
eliminates possibility of exposing<br />
the cutting head to operators <strong>and</strong><br />
equipment<br />
Guiding rope system that helps<br />
ensure personnel are always at a safe<br />
distance from the tool when it is<br />
being placed into or removed from<br />
the well<br />
Safety features based on worst-case<br />
scenarios <strong>and</strong> tested under actual<br />
conditions to help provide quick<br />
responses to any situation<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-39
Caution: Prior to every chemical cutter job, <strong>Halliburton</strong><br />
strongly recommends checking for restrictions in the well by<br />
performing a gauge run <strong>and</strong> string shot.<br />
Tool Size in.<br />
(Anchor And Sev Head)<br />
<strong>Halliburton</strong>’s chemical cutter supplier is Pipe Recovery<br />
Systems Inc. (PRS).<br />
Selection Guide for Coiled Tubing Chemical Cutter<br />
Tool Specifications Coiled Tubing Specifications<br />
Max. Extension<br />
of Wedges/Slips in.<br />
4-40 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
OD<br />
in.<br />
ID<br />
in.<br />
Weight<br />
lb/ft<br />
*11/16 0.92 1 0.782 - 0.810 0.918 - 1.037<br />
*3/4 1.05 1 0.826 - 0.866 0.688 - 0.848<br />
*13/16 1.09 1 1/4 0.938 - 1.076 1.081 - 1.823<br />
*7/8 1.11 1 1/4 1.032 - 1.076 1.081 - 1.328<br />
*15/16 1.15 1 1/4 1.100 - 1.116 0.840 - 0.941<br />
*1 1.33 1 1/2 1.188 - 1.282 1.619 - 2.239<br />
*1 1/16 1.35 1 1/2 1.188 - 1.282 1.619 - 2.239<br />
*1 1/8 1.42 1 1/2 1.282 - 1.334 1.256 - 1.619<br />
*1 3/16 1.51 1 3/4 1.374 - 1.500 2.169 - 3.136<br />
*1 1/4 1.61 1-3/4 1.400 - 1.532 1.910 - 2.944<br />
1 3/8 1.80 2 1.594 - 1.688 3.072 - 3.896<br />
1 1/2 2.04 2 1.732 - 1.782 2.201 - 2.671<br />
1 11/16 2.20 2 3/8 1.969 - 2.025 4.112 - 4.709<br />
1 7/8 2.55 2 3/8 2.063 - 2.157 2.638 - 4.709<br />
2 1/8 2.60 2 7/8 2.469 - 2.563 4.530 - 5.793<br />
2 5/8<br />
* Denotes wedge type anchor<br />
3.35 3 1/2 3.094 - 3.150 6.215 - 7.148<br />
Tool Size<br />
(Anchor And Sev Head)<br />
Selection Guide for CS Hydril Tubing 1.050 - 1.660 OD<br />
Tool Specifications<br />
in. Tubing Specifications<br />
Max. Extension<br />
of Wedges/Slips<br />
OD<br />
in.<br />
ID<br />
in.<br />
Weight<br />
lb/ft<br />
*11/16 0.92 1.05 0.824 1.200<br />
*3/4 1.05 1.315 0.957 2.250<br />
*13/16 1.09 1.315 1.049 1.800<br />
*1 1/16 1.35 1.660 1.278 3.020<br />
*1 3/16<br />
* Denotes wedge type anchor<br />
1.51 1.660 1.380 - 1.410 2.100 - 2.400
Tool Size<br />
(Anchor And Sev Head)<br />
in.<br />
* 6-slip anchor only<br />
Selection Guide — Tubing for D/A Chemical Cutter<br />
Tool Specifications Tubing Specifications<br />
Max. Extension<br />
of Wedges/Slips<br />
in.<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-41<br />
OD<br />
in.<br />
ID<br />
in.<br />
Weight<br />
lb/ft<br />
1 3/8 1.80 1.90 1.500 - 1.650 2.40 - 3.64<br />
1 1/2 2.04<br />
2 1/16 1.670 - 1.751 3.25 - 3.40<br />
2 3/8 1.703 - 1.995 4.70 - 7.70<br />
1 9/16 2.10 2 3/8 1.853 - 1.995 4.70 - 6.20<br />
1 11/16 2.20 2 3/8 1.939 - 1.995 4.70 - 5.30<br />
1 3/4 2.50 2 7/8 2.059 - 2.441 6.50 - 10.70<br />
1 7/8 2.55 2 7/8 2.059 - 2.441 6.50 - 10.70<br />
2 2.58 2 7/8 2.195 - 2.441 6.50 - 9.50<br />
2 1/8 2.60 2 7/8 2.323 - 2.441 6.50 - 7.90<br />
2 E.R. 2.85 3 1/2 2.480 - 2.750 12.95 - 16.70<br />
2 1/8 E.R. 3.10 3 1/2 2.480 - 2.992 9.30 - 16.70<br />
2 3/16 3.10 3 1/2 2.480 - 2.992 9.30 - 16.70<br />
2 1/4 3.15 3 1/2 2.602 - 2.992 9.30 - 15.50<br />
2 3/8 3.25 3 1/2 2.602 - 3.068 7.70 - 15.50<br />
*2 5/8 3.35 3 1/2 2.922 - 3.068 7.70 - 10.30<br />
*2 7/8 3.65 4 3.240 - 3.476 11.00 - 15.70<br />
*3 1/8 3.92 4 3.340 - 3.548 9.50 - 14.00<br />
*3 1/4 4.04 4 1/2 3.640 - 3.958 12.60 - 20.00<br />
*3 3/8 4.16 4 1/2 3.697 - 4.000 11.60 - 17.70<br />
*3 1/2 4.28 4 1/2 3.826 - 4.090 9.50 - 15.50<br />
*3 5/8 4.40 4 1/2 3.920 - 4.090 9.50 - 13.50<br />
*3 7/8 4.68 5 4.154 - 4.408 15.00 - 21.00<br />
*4 4.80 5 4.276 - 4.560 11.50 - 19.50<br />
*4 3/16 4.92 5 1/2 4.548 - 4.778 20.00 - 26.00<br />
*4 7/16 5.14 5 1/2 4.670 - 4.950 15.50 - 23.00<br />
*4 9/16 5.14 5 1/2 4.892 - 5.044 13.00 - 17.00<br />
5 1/2 6.50 7 6.004 - 6.214 28.00 - 35.00<br />
5 3/4 6.50 7 6.276 - 6.456 20.00 - 26.00<br />
6 3/8 7.37 7 5/8 6.765 - 7.125 20.00 - 33.70
Tubing Cutters<br />
Jet Research Center’s tubing cutters are designed to cleanly<br />
sever a wide range of tubing quickly <strong>and</strong> efficiently. These<br />
proven design cutters are the world’s most widely used <strong>and</strong><br />
have a performance record that is unsurpassed. The tubing<br />
cutter range includes industry-leading ceramic cap designs<br />
for minimum debris to economic cast iron versions for costeffective<br />
solutions. JRC tubing cutters offer high reliability in<br />
field applications with a minimum amount of set-up or<br />
configuration based on well parameters. JRC tubing cutters<br />
<strong>and</strong> method of assembly are patented technology (US Patent<br />
5,129,322). Tubing cutters can be used with JRC’s<br />
proprietary RED® rig environment detonator, offering a high<br />
level of protection against stray voltage or inadvertent RFinitiation.<br />
Features<br />
High strength ceramic cap provides 20,000 psi pressure<br />
rating<br />
Breakup characteristic of the ceramic design leaves<br />
minimal debris in the well<br />
Cutter design features minimum flare characteristic for<br />
ease of recovery<br />
Extensive cutter range offers selection based on well<br />
conditions<br />
Cutters available for high strength <strong>and</strong> chrome material<br />
Special designs available to match unique well conditions<br />
Detonator options available to satisfy all applications<br />
Tubing Cutters<br />
4-42 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL11763
Tubing<br />
OD in.<br />
2 1/16<br />
2 3/8<br />
2 3/8<br />
2 3/8<br />
2 3/8<br />
2 3/8<br />
2 7/8<br />
2 7/8<br />
2 7/8<br />
2 7/8<br />
2 7/8<br />
2 7/8<br />
3 1/2<br />
3 1/2<br />
3 1/2<br />
3 1/2<br />
Description Part No.<br />
1 9/16-in.<br />
Tubing Cutter<br />
1 11/16-in.<br />
Tubing Cutter<br />
1 11/16-in.<br />
Tubing Cutter<br />
(Cast Iron)<br />
1 23/32-in.<br />
Tubing Cutter<br />
1 13/16-in.<br />
Tubing Cutter<br />
1 13/16-in.<br />
Tubing Cutter<br />
(Cast Iron)<br />
2 1/32-in.<br />
Tubing Cutter<br />
2 1/8-in.<br />
Tubing Cutter<br />
2 1/8-in.<br />
Tubing Cutter<br />
(Cast Iron)<br />
2 1/8-in.<br />
Hastelloy<br />
Tubing Cutter<br />
2 1/4-in.<br />
Tubing Cutter<br />
2 1/4-in.<br />
Tubing Cutter<br />
(Cast Iron)<br />
2 1/2-in.<br />
Tubing Cutter<br />
(Cast Iron)<br />
2 19/32-in.<br />
Tubing Cutter<br />
2.70-in.<br />
Tubing Cutter<br />
2.70-in.<br />
Hastelloy<br />
Tubing Cutter<br />
Cutter OD<br />
in.<br />
Rating<br />
psi / °F<br />
Tubing Cutters<br />
Explosive<br />
weight g<br />
Housing<br />
Material<br />
100083086 1.563 15,000/400 4 Ceramic<br />
100000352 1.688 20,000/400 8.5 Ceramic<br />
101288527 1.688 12,500/400 8.5 Cast Iron<br />
100000570 1.719 20,000/400 8.5 Ceramic<br />
100000353 1.813 20,000/400 8.5 Ceramic<br />
101290400 1.813 12,500/400 8.5 Cast Iron<br />
100000354 2.031 20,000/400 15.4 Ceramic<br />
100000355 2.125 20,000/400 15.4 Ceramic<br />
101290402 2.125 12,500/400 15.4 Cast Iron<br />
100000430 2.125 20,000/400 33 Ceramic<br />
100000356 2.250 20,000/400 13 Ceramic<br />
101290405 2.250 12,500/400 13 Cast Iron<br />
101290406 2.500 12,500/400 22.5 Cast Iron<br />
100116367 2.594 20,000/400 22.5 Ceramic<br />
100011034 2.700 20,000/400 22.5 Ceramic<br />
100000431 2.700 20,000/400 46 Ceramic<br />
Shipping<br />
Class<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.1D<br />
UN0059<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.1D<br />
UN0059<br />
Recommended Target Tubing<br />
Grade Wall Th<br />
(Incl<br />
Coupl.) lb/ft<br />
P105 0.216 3.25<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-43<br />
P105<br />
P105<br />
P105<br />
P105<br />
P105<br />
0.190 -<br />
0.254<br />
0.190 -<br />
0.254<br />
0.190 -<br />
0.254<br />
0.190 -<br />
0.254<br />
0.190 -<br />
0.254<br />
4.70 - 5.95<br />
4.70 - 5.95<br />
4.70 - 5.95<br />
4.70 - 5.95<br />
4.70 - 5.95<br />
P105 0.308 6.50 - 8.70<br />
P105 0.217 6.50<br />
P105 0.217 6.50<br />
Chrome 0.276 7.90<br />
P105 0.217 6.50<br />
P105 0.217 6.50<br />
P105<br />
P105<br />
P105<br />
Chrome<br />
0.254 -<br />
0.449<br />
0.254 -<br />
0.289<br />
0.254 -<br />
0.289<br />
0.254 -<br />
0.289<br />
9.3 - 15.50<br />
9.30 - 10.30<br />
9.30 - 10.30<br />
9.30 - 10.30
Super Tubing Cutters<br />
Jet Research Center’s super tubing cutters are designed where<br />
well conditions prevent the use of a conventional tubing<br />
cutter based on unexpected or severe restrictions. In this<br />
situation, a specially designed cutting charge is used. The<br />
cutter is based on a conventionally shaped charge assembly<br />
but has additional explosive in the form of a pelletized charge<br />
in the base of the cutter. It is a smaller diameter than a<br />
conventional charge for the pipe to be cut. The cutter can<br />
easily pass through tight restrictions <strong>and</strong> still achieve<br />
severance. Based on the design constraints, some tubing<br />
deformation at the cut point is likely with this cutter. Super<br />
tubing cutters can be used with JRC’s proprietary RED® rig<br />
environment detonator, offering a high level of protection<br />
against stray voltage or inadvertent RF initiation.<br />
Features<br />
High strength steel cap provides 20,000 psi pressure<br />
rating<br />
Reduced diameter easily passes wellbore restrictions<br />
Detonator options available to satisfy all applications<br />
Two cutter sizes for common tubing sizes<br />
Special designs available to match unique well conditions<br />
Super Tubing Cutters<br />
4-44 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL11763
Tubing<br />
OD in.<br />
2 3/8<br />
2 7/8<br />
Description Part No.<br />
1 9/16-in. Super<br />
Cutter<br />
1 13/16-in.<br />
Super Cutter<br />
100005493<br />
+100158162<br />
100008057<br />
+100158161<br />
Cutter OD<br />
in.<br />
Super Tubing Cutters<br />
Rating<br />
psi / °F<br />
Explosive<br />
weight g<br />
Housing<br />
Material<br />
(S-Steel)<br />
1.563 20,000/400 40 S<br />
1.813 20,000/400 40 S<br />
Accessories<br />
Shipping<br />
Class<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
Recommended Target Tubing<br />
Grade Wall Th<br />
(Incl<br />
Coupl.) lb/ft<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-45<br />
N80<br />
N80<br />
0.190 -<br />
0.254<br />
0.217 -<br />
0.308<br />
Tubing Cutter Accessories HP Accessories Safety Accessories<br />
Detonator - Resistorized 100000432 Extension M<strong>and</strong>rel - Steel 101293227 Shunt Plug 100010861<br />
Firing Head, 1 1/2-in. OD 100000434 Adapter for RED - Steel 101293230 Safety Tube 100010862<br />
Extension M<strong>and</strong>rel 100008258<br />
Detonator - RED ®<br />
101272595<br />
Adapter for RED Detonator 101293676<br />
Notes:<br />
1. Undersized cutters may not make a full cut.<br />
2. Always run effective centralization for optimum results.<br />
3. Field assembly required due to shipping features.<br />
4. CAUTION: Not recommended for casing sizes less than 7 in.<br />
4.70 - 5.95<br />
6.50 - 8.70
Coiled Tubing Cutters<br />
Jet Research Center’s coiled tubing cutters are designed to<br />
cleanly sever common sizes of tubing quickly <strong>and</strong><br />
economically. These proven design cutters are widely used<br />
<strong>and</strong> have an unsurpassed performance record.<br />
Features<br />
High strength steel components allow successful trip<br />
inside the coiled tubing<br />
Corrosion resistant components<br />
Cutters sizes available for 1, 1.25, 1.5 <strong>and</strong> 1.75-in. coiled<br />
tubing<br />
13.75-in. cutter suitable for cutting 1.5-in. (1.900) NU<br />
API tubing<br />
Compatible with industry st<strong>and</strong>ard wireline accessories<br />
Can be designed with high temperature explosives for<br />
special applications<br />
Coiled Tubing Cutters<br />
4-46 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL11764
Tubing<br />
OD in.<br />
1.00<br />
1.25<br />
1.50<br />
1.75<br />
1.90<br />
Description Part No.<br />
0.718-in. Coiled<br />
Tubing Cutter<br />
0.948-in.<br />
Coiled Tubing<br />
Cutter<br />
1 3/16-in.<br />
Coiled Tubing<br />
Cutter<br />
1 3/8-in.<br />
Tubing Cutter<br />
1 3/8-in.<br />
Tubing Cutter<br />
Cutter OD<br />
in.<br />
Coiled Tubing Cutters<br />
Rating<br />
psi / °F<br />
Explosive<br />
weight g<br />
Housing<br />
Material<br />
(S-Steel)<br />
100118388 0.718 10,000/325 1 S<br />
100118389 0.948 10,000/325 2.9 S<br />
100000429 1.188 10,000/325 4.7 S<br />
100000569 1.375 15,000/400 4 S<br />
100000569 1.375 15,000/400 4 S<br />
Accessories<br />
Shipping<br />
Class<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
1.4S<br />
UN0441<br />
Accessories Safety Accessories<br />
Recommended Target Tubing<br />
Grade Wall Th<br />
Weight<br />
(Incl<br />
Coupl.) lb/ft<br />
N80 0.081 0.786<br />
N80 0.095 1.172<br />
N80 0.109 1.619<br />
N80 0.134 2.313<br />
P105 0.145 2.900<br />
Detonator - Resistorized 100010855 Safety Tube for Detonator 100158234<br />
5/8-in. OD Cont Sub (1.59 cm) 100005498 0.5-20 UNF-2A (thread) 5/8-in. Shunt Plug 100158235<br />
3/4-in. OD Cont Sub (1.91 cm) 100158243 0.555-28P-36-SA (thread) 3/4-in. Shunt Plug 120042542<br />
1-in. OD Cont Sub (2.54 cm) 100014497 0.812-16 UN-2A (thread) 1-in. Shunt Plug 120042541<br />
Notes:<br />
1. Always run effective centralization for optimum results.<br />
2. Undersized cutters may not make a full cut.<br />
3. When more than one cutter is available for the specification, always select the largest diameter cutter.<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-47
Casing <strong>and</strong> Drillpipe Cutters<br />
Jet Research Center’s casing <strong>and</strong> drillpipe cutters feature the<br />
same level of engineering detail <strong>and</strong> design as the industryleading<br />
JRC tubing cutters. They are designed to cleanly sever<br />
a wide range of casing efficiently, using a minimum amount<br />
of explosive. The designs feature high specification<br />
aluminum alloy case material that breaks up substantially<br />
upon detonation. JRC casing <strong>and</strong> drillpipe cutters offer high<br />
levels of safety <strong>and</strong> reliability in field applications with a<br />
minimum amount of set-up or configuration based on well<br />
parameters. JRC developed the industry st<strong>and</strong>ard shock<br />
attenuating m<strong>and</strong>rel for use with the range of casing <strong>and</strong><br />
drillpipe cutters <strong>and</strong> patented this technology (US patent<br />
5,117,911). Casing <strong>and</strong> drillpipe cutters can be used with<br />
JRC’s proprietary RED® rig environment detonator, offering<br />
a high level of protection against stray voltage or inadvertent<br />
RF-initiation.<br />
Features<br />
Shock attenuating m<strong>and</strong>rel helps protect associated<br />
wireline tools<br />
Cutter designed for minimum pipe flare<br />
Extensive cutter range offers selection based on well<br />
conditions<br />
Cutters available for high-strength <strong>and</strong> chrome pipes<br />
Special designs available to match unique well conditions<br />
Detonator options available to satisfy all applications<br />
Casing <strong>and</strong> Drillpipe Cutters<br />
4-48 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL11765
Tubing<br />
OD<br />
in.<br />
3 1/2 DP<br />
4<br />
4 1/2 DP<br />
4 1/2 DP<br />
5 DP<br />
4 1/2<br />
5<br />
5 DP<br />
5 1/2<br />
5 1/2<br />
5 3/4<br />
6<br />
6 5/8<br />
6 5/8<br />
7<br />
7<br />
7 5/8<br />
8 5/8<br />
9 5/8<br />
Description Part No.<br />
2 3/8-in. Drill<br />
Pipe Cutter<br />
2 15/16-in. Drill<br />
Pipe Cutter<br />
2 5/16-in. Drill<br />
Pipe Cutter<br />
3 15/16- in.<br />
Drill Pipe Cutter<br />
3 5/16-in.<br />
Drill Pipe Cutter<br />
3 5/8-in.<br />
Casing Cutter<br />
4-in.<br />
Casing Cutter<br />
4-in.<br />
Casing Cutter<br />
4 1/2-in.<br />
Casing Cutter<br />
4 3/4-in.<br />
Casing Cutter<br />
4 3/4-in.<br />
Casing Cutter<br />
5 3/8-in.<br />
Casing Cutter<br />
5 3/8-in.<br />
Casing Cutter<br />
5 1/2-in.<br />
Casing Cutter<br />
5 1/2-in.<br />
Casing Cutter<br />
6- in.<br />
Casing Cutter<br />
6 1/8-in.<br />
Casing Cutter<br />
7 1/4-in.<br />
Casing Cutter<br />
8 3/16-in.<br />
Casing Cutter<br />
Cutter OD<br />
in.<br />
Wafer Casing Cutters (1.1D)<br />
Rating<br />
psi / °F<br />
Explosive<br />
Weight g<br />
Housing<br />
Material<br />
(S-Steel,<br />
A-Aluminum)<br />
100116368 2.375 12,500/400 22 S/A<br />
100127821 2.938 7,500/400 47.4 A<br />
100127821 2.938 7,500/400 47.4 A<br />
100000140 3.313 7,500/400 61 A<br />
100000140 3.313 7,500/400 61 A<br />
101293449 3.625 7,500/400 54 A<br />
101293457 4.000 9,000/400 110 S/A<br />
101293457 4.000 9,000/400 110 S/A<br />
100014494 4.500 9,000/400 104 S/A<br />
101293484 4.750 9,000/400 100 S/A<br />
101293484 4.750 9,000/400 100 S/A<br />
101293491 5.375 9,000/400 240 S/A<br />
101293491 5.375 9,000/400 240 S/A<br />
101293515 5.500 9,000/400 253 A<br />
101293515 5.500 9,000/400 253 A<br />
101293536 6.000 9,000/400 280 A<br />
101293544 6.125 9,700/400 253 A<br />
101293553 7.250 8,000/400 373 A<br />
101293555 8.188 8,000/400 407 A<br />
Accessories<br />
Shipping<br />
Class<br />
1.4S<br />
UN0441<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
1.1D<br />
UN0059<br />
Recommended Target Tubing<br />
Grade Wall Th<br />
Weight (Incl<br />
Coupl.) lb/ft<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-49<br />
G105<br />
L80<br />
G105<br />
0.254 -<br />
0.449<br />
0.262 -<br />
0.380<br />
0.271 -<br />
0.430<br />
9.5 - 15.5<br />
11.85 -<br />
15.7<br />
13.75 -<br />
20.00<br />
G105 0.430 20.00<br />
G105<br />
L80<br />
L80<br />
G105<br />
L80<br />
L80<br />
L80<br />
L80<br />
0.296 -<br />
0.500<br />
0.205 -<br />
0.337<br />
0.253-<br />
0.437<br />
0.296 -<br />
0.362<br />
0.304 -<br />
0.415<br />
0.244 -<br />
0.304<br />
0.330 -<br />
0.430<br />
0.224 -<br />
0.275<br />
16.25 -<br />
25.60<br />
9.50 -<br />
15.10<br />
11.50 -<br />
21.40<br />
16.25 -<br />
19.50<br />
17.00 -<br />
23.00<br />
14.00 -<br />
17.00<br />
19.50 -<br />
25.20<br />
14.00 -<br />
17.00<br />
L80 0.475 32.00<br />
L80<br />
L80<br />
L80<br />
L80<br />
L80<br />
L80<br />
0.228 -<br />
0.417<br />
0.408 -<br />
0.540<br />
0.317 -<br />
0.408<br />
0.375 -<br />
0.500<br />
0.400 -<br />
0.595<br />
0.435 -<br />
0.545<br />
Tubing Cutter Accessories HP Accessories Safety Accessories<br />
Detonator - Resistorized 100000432 Extension M<strong>and</strong>rel - Steel 101293227 Shunt Plug 100010861<br />
Adapter for Resistorized Detonator 100014468<br />
Adapter for Resistorized<br />
Detonator - Steel<br />
Firing Head, 1 1/2-in. OD 100000434 Adapter for RED - Steel 101295134<br />
Extension M<strong>and</strong>rel 100008258<br />
Detonator - RED ®<br />
101272595<br />
Adapter for RED Detonator 101295128<br />
Notes:<br />
1. Always run effective centralization for optimum results.<br />
2. Undersized cutters may not make a full cut.<br />
3. When more than one cutter is available for the specified target, always select the largest diameter cutter.<br />
20.00 -<br />
28.00<br />
29.00 -<br />
38.00<br />
23.00 -<br />
29.00<br />
29.70 -<br />
39.00<br />
36.00 -<br />
52.00<br />
43.50 -<br />
53.50<br />
101293240 Safety Tube 100010862
C-4 Casing Cutters<br />
Jet Research Center’s C-4 casing cutters are designed to allow<br />
air transportation (via commercial aircraft) of the explosives<br />
in individual packages. Air freight allows for rapid shipment<br />
of urgently needed cutters <strong>and</strong> is considerably less expensive<br />
than transportation by sea. Upon arrival at the location, the<br />
explosive can then be placed in the cutter body <strong>and</strong> run in<br />
the well.<br />
The C-4 cutters then function as traditional cutters, except<br />
for their reduced temperature limitation. This product line<br />
uses the same safe-arming procedures as the popular tubing,<br />
drillpipe, <strong>and</strong> normal casing cutters. It allows the detonator<br />
to be electronically connected safely before the detonator is<br />
placed in proximity to the cutting charge.<br />
Applications<br />
Emergency situation where cutter must be flown<br />
to wellsite<br />
Temperature limitation of 225°F<br />
Pressure limitations depend on the size of the cutter<br />
Features<br />
Patented shock absorber m<strong>and</strong>rel helps protect CCLs<br />
<strong>and</strong> other associated hardware<br />
Aluminum case components allow easy breakup of<br />
components into debris<br />
Detonation options available to satisfy all applications<br />
Available in sizes to cut 4.5-in. to 9.625-in. casing<br />
Upon request, test shots can be made in special pipe to<br />
verify performance<br />
C-4 Casing Cutters<br />
4-50 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL11765
Drill Collar Severing Tool<br />
Jet Research Center developed the dual end severing tool for<br />
severing thick wall tubulars over 20 years ago. The technique<br />
is based on the colliding shock wave principle. Since its<br />
inception, the drill collar severing tool has been continuously<br />
refined, resulting in the industry-leading severance device for<br />
cutting drill collars <strong>and</strong> drillpipe in a wide variety of stuck<br />
pipe scenarios. The latest refinement to the tool has resulted<br />
in a st<strong>and</strong>ard explosive column length with superior<br />
performance. The secret to the success of the tool lies in the<br />
precisely-timed detonation of two equal <strong>and</strong> opposing shock<br />
fronts. The colliding shock is matched to a cartridge<br />
assembly at the mid-point of the assembly, designed to help<br />
focus the energy transmitted to the target. JRC developed the<br />
industry st<strong>and</strong>ard shock attenuating m<strong>and</strong>rel for use with<br />
drill collar severing tools <strong>and</strong> patented this technology (US<br />
patent 5,117,911). Drill collar severing tools can be used with<br />
JRC’s proprietary RED® rig environment detonator, offering<br />
a high level of protection against stray voltage or inadvertent<br />
RF initiation.<br />
Applications<br />
Cutting drill collars <strong>and</strong> drillpipe in situations involving<br />
stuck pipe<br />
Features<br />
Redesigned in 2002 for maximum performance<br />
Full range of sizes for virtually any severing requirement<br />
Suitable for hostile environment up to 400°F, 20,000 psi<br />
Higher temperature tools available for extreme<br />
temperature application<br />
Shock attenuating m<strong>and</strong>rel helps protect wireline tools.<br />
Quick assembly <strong>and</strong> deployment<br />
Industry st<strong>and</strong>ard connections can be run on any<br />
wireline unit<br />
Air freight classification (1.4s) provides rapid<br />
mobilization<br />
Drill Collar Severing Tool<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-51<br />
HAL11766
Tool OD<br />
in. (cm) Temperature <strong>and</strong> Pressure Rating<br />
1 3/8<br />
(3.5)<br />
1 3/4<br />
(4.4)<br />
2<br />
(5.1)<br />
2 5/8<br />
(6.7)<br />
HMX - 400°F (204°C)<br />
20,000 psi (138 Mpa) for 1 hour*<br />
HNS - 475°F (246°C)<br />
20,000 psi (138 Mpa) for 1 hour*<br />
HMX - 400°F (204°C)<br />
20,000 psi (138 Mpa) for 1 hour*<br />
HNS - 475°F (246°C)<br />
20,000 psi (138 Mpa) for 1 hour*<br />
HMX - 400°F (204°C)<br />
20,000 psi (138 Mpa) for 1 hour*<br />
HNS - 475°F (246°C)<br />
20,000 psi (138 Mpa) for 1 hour*<br />
HMX - 400°F (204°C)<br />
20,000 psi (138 Mpa) for 1 hour*<br />
HNS - 475°F (246°C)<br />
20,000 psi (138 Mpa) for 1 hour*<br />
Drill Collar Capability Chart<br />
Length<br />
in.<br />
Designed to<br />
Sever up to<br />
in.<br />
Explosive Pellet<br />
Weight<br />
g<br />
Cartridge<br />
Assembly<br />
Explosive<br />
Weight<br />
g<br />
Loaded Tool<br />
Weight<br />
g<br />
36 3 1/2 OD DCs 20.7 × 28 pellets 4.8 × 2 589.2<br />
36 6 1/2 OD DCs 22.7 × 44 pellets 12.7 × 2 1024.2<br />
36 8 OD DCs 22.7 × 64 pellets 17.4 × 2 1487.8<br />
36 11 OD DCs 21.5 × 110 pellets 28.5 × 2 2422.1<br />
* For high pressure application, in excess of 15,000 psi, JRC recommends the use of high pressure steel rated accessories.<br />
4-52 Cased-Hole <strong>Wireline</strong> <strong>Services</strong>
Junk Shot<br />
Jet Research Center’s junk shots have been field proven time<br />
after time in a wide variety of applications all over the world.<br />
The junk shot charge has been used to overcome some of the<br />
most challenging fishing operations encountered, ranging<br />
from breaking up complete drilling bits to underreamer<br />
arms. The junk shot is a large downward shooting shaped<br />
charge secured inside a pressure housing.When placed on top<br />
of the junk, it functions in a similar manner as a perforating<br />
charge, but the explosive effect is substantially greater with<br />
the ability to destroy large targets. In almost any situation,<br />
the use of the junk shot charge to break up obstacles<br />
downhole reduces costly fishing time, returning the rig to full<br />
operation.<br />
Applications<br />
Break up obstacles downhole <strong>and</strong> return rig to full operation<br />
Features<br />
Main charge run on wireline, drillstring, or tubing with a<br />
secondary wireline initiator for maximum effect<br />
Two sizes of charge available: 5.25-in. OD <strong>and</strong> 7.75-in. OD<br />
Tools may be clustered for special applications<br />
Can be transported via air charter or st<strong>and</strong>ard ground<br />
services<br />
Pressure rated to 18,000 psi<br />
Temperature rated to 400°F for one hour<br />
Offers a high degree of safety due to its two-stage<br />
deployment<br />
Offers a safe assembly method through the use of JRC’s<br />
safe arming equipment<br />
Can be run on wireline or tubing<br />
Can be fired electronically or hydraulically<br />
Junk Shot<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-53<br />
HAL11767
Plug Setting Equipment<br />
EZ Drill ® Bridge Plugs<br />
EZ Drill® bridge plugs consist of an EZ Drill SV packer from<br />
which the sliding valve has been removed <strong>and</strong> a bridging plug<br />
has been added. This combination offers excellent downhole<br />
pressure control <strong>and</strong> drillability.<br />
Applications<br />
Downhole pressure control <strong>and</strong> drillability<br />
Features<br />
Built from cast iron, brass, aluminum, <strong>and</strong> rubber<br />
Ability to be set on:<br />
– Electric wireline<br />
– Slickline<br />
–Coiled tubing<br />
– Jointed pipe with a mechanical or hydraulic<br />
setting tool<br />
Can be used with conventional tricone bits or junk-style<br />
mills<br />
EZ Drill® Bridge Plug<br />
4-54 Cased-Hole <strong>Wireline</strong> <strong>Services</strong><br />
HAL9254
Fas Drill ® Bridge Plugs<br />
The Fas Drill® bridge plug allows oil <strong>and</strong> gas operators to run<br />
multiple drillable bridge plugs in a well for stimulation <strong>and</strong><br />
workover operations, then drill out in one fast, easy<br />
operation.<br />
Fas Drill bridge plugs are used in a manner similar to<br />
conventional, drillable bridge plugs <strong>and</strong> can be set on tubing,<br />
on drillpipe, or with conventional tools, such as electric<br />
wireline. An adaptor kit is required for setting tools. Setting<br />
equipment <strong>and</strong> operation are identical for both versions.<br />
St<strong>and</strong>ard Fas Drill bridge plugs have operational limits of<br />
250°F with 5,000 psi differential from either direction. HPHT<br />
models have operating limits of 350°F with an 8,000 or<br />
10,000 psi differential.<br />
Applications<br />
Run multiple drillable bridge plugs for stimulation <strong>and</strong><br />
workover operations<br />
Features<br />
Consists of composites <strong>and</strong> a packer set, giving it<br />
minimal ferrous metal content<br />
Can be set with electric wireline setting tools, slickline<br />
setting tools, coiled tubing setting tools, or mechanical<br />
setting tools<br />
Isolates lower zones during squeeze cementing<br />
operations on l<strong>and</strong>-based or offshore rigs in vertical or<br />
deviated wells<br />
Functions as a bridge plug in multizone stimulation<br />
treatments<br />
Fas Drill® Bridge Plug<br />
Cased-Hole <strong>Wireline</strong> <strong>Services</strong> 4-55<br />
HAL12041
4-56 Cased-Hole <strong>Wireline</strong> <strong>Services</strong>
<strong>Perforating</strong> Solutions<br />
<strong>Perforating</strong> Solutions maintains an unequalled success <strong>and</strong><br />
safety record while continuously developing <strong>and</strong> introducing<br />
new <strong>and</strong> innovative products for tubing conveyed <strong>and</strong><br />
wireline perforating.<br />
Shaped Charges<br />
<strong>Halliburton</strong> shaped charges lead the way in quality, reliability<br />
<strong>and</strong> performance. <strong>Halliburton</strong> ballistic engineers at Jet<br />
Research Center continue to develop <strong>and</strong> manufacture<br />
perforating systems for virtually any reservoir environment<br />
or intervention technique. <strong>Halliburton</strong> also has the capability<br />
<strong>and</strong> expertise to develop custom charges to maximize<br />
effective penetration into specific reservoirs.<br />
MaxForce Shaped Charges<br />
The new MaxForce line of super-deep penetrating charges<br />
is Jet Research Center's latest advancement in shaped charge<br />
evolution. The MaxForce line of charges is manufactured<br />
with the highest level of quality assurance that results in a<br />
lower st<strong>and</strong>ard deviation to provide consistent charge<br />
performance.<br />
Features<br />
MaxForce deeper penetration charges:<br />
Increase productivity<br />
Penetrate past any near wellbore damage with deeper<br />
penetration<br />
Potentially intersect more natural fractures with deeper<br />
penetration<br />
Reduce pressure drop at perforations, which can<br />
potentially delay scale, paraffin, or asphaltene deposits<br />
<strong>Perforating</strong> Solutions 5-1<br />
2007<br />
2000<br />
1995<br />
1990<br />
DP (HNS)<br />
Super DP<br />
HAL16785<br />
MaxForce<br />
Millennium<br />
<strong>Perforating</strong> Solutions
Dominator ® Shaped Charges<br />
The Dominator® shaped charges are designed to optimize<br />
perforating performance in reservoir rock <strong>and</strong> increase<br />
hydrocarbon production. To achieve that goal, Dominator<br />
charges were evaluated in terms of geometry <strong>and</strong> flow<br />
performance in s<strong>and</strong>stone targets at simulated downhole<br />
conditions instead of by their ability to penetrate API 19B<br />
Section I unstressed concrete. As a result, these new shaped<br />
charges far exceed the performance of current, comparable<br />
charges.<br />
A Revolutionary Approach to Charge Development<br />
To maximize well inflow performance for a specific reservoir,<br />
it is necessary to engineer the shaped-charge explosive jet-tip<br />
velocity profile with consideration to the target properties<br />
(compressive strength, particle grain size, pore fluid type,<br />
etc.). Optimized shaped charge design combined with<br />
perforating best practices per <strong>Halliburton</strong>’s PerfPro® process<br />
ensure that all perforations are surged at the optimum<br />
underbalance pressure to minimize perforation skin effects.<br />
Naturally, shaped charges engineered for a given reservoir<br />
should be validated with API 19B Section IV testing (i.e.<br />
Perforation Flow Laboratory) at as close to in-situ properties<br />
as possible.<br />
Dominator shaped charges were developed at <strong>Halliburton</strong>’s<br />
Jet Research Center (JRC) Perforation Flow Laboratory by<br />
firing perforating charges into real rock under simulated<br />
downhole conditions that included rock effective stress,<br />
wellbore underbalance, <strong>and</strong> rock pore pressure. By analyzing<br />
post-shot results from the testing program, it was possible to<br />
rapidly develop a design with favorable jet characteristics.<br />
Using the perforation flow laboratory in the design process<br />
also avoided the pitfalls associated with translating data from<br />
surface shot concrete targets to productivity estimations in<br />
downhole reservoirs.<br />
The improvement in penetration performance is evident<br />
from the results. In one example, penetration increased by an<br />
average of 52% in the gas-filled samples <strong>and</strong> by an average of<br />
37% in liquid-filled samples. These penetration results, along<br />
with improvement in core flow efficiency, contribute to<br />
increased flow performance.<br />
Exp<strong>and</strong>ing case<br />
fragments<br />
Rearmost<br />
portion of jet<br />
Stretching jet<br />
Jet tip<br />
Flash X-ray of a charge during detonation sequence<br />
5-2 <strong>Perforating</strong> Solutions<br />
HAL15999<br />
HAL15956<br />
Actual charge performance in formation core samples comparing<br />
st<strong>and</strong>ard charge on left vs the Dominator® charge on the right.<br />
HAL15957
Mirage ® Shaped Charges<br />
The Mirage® line of BH shaped charges was introduced as an<br />
improved low debris system. The Mirage line provides more<br />
of a total perforating system debris reduction solution. With<br />
the Mirage line, gun debris associated with all components of<br />
the perforating assembly is reduced.<br />
Previous BH guns systems required that the shaped charges<br />
be positioned <strong>and</strong> retained in the charge tube holder using<br />
bend tabs. The bend tab is a significant source of gun debris<br />
because of the metal slivers generated during gun detonation.<br />
The improved Mirage system incorporates a new twist lock<br />
feature in the charge tube holder, eliminating the debris<br />
associated with the bend tabs.<br />
In addition to metallurgical considerations, the geometry of<br />
the Mirage shaped charge liner is carefully controlled during<br />
the manufacturing process such that those portions of the<br />
liner that might contribute to slug creation are removed. This<br />
process results in a charge liner with a controlled geometry<br />
liner (CGL).<br />
“Thick” region<br />
controlled to<br />
reduce debris<br />
“Thinned” region<br />
after forming<br />
HAL16270<br />
Mirage® Super Hole Perforator<br />
Initial (Copper) 7-in. BH Liner Technology<br />
Current (Brass) 7-in. BH Liner Technology<br />
Latest (Mirage®) 7-in. BH Liner Technology<br />
<strong>Perforating</strong> Solutions 5-3<br />
HAL16361<br />
HAL16360<br />
HAL16366
The LD zinc charge cases with the Mirage® system have been optimized to reduce the particle size distribution as shown below.<br />
Mass Retained (g)<br />
HAL16267<br />
70.0<br />
60.0<br />
50.0<br />
40.0<br />
30.0<br />
20.0<br />
10.0<br />
Case Debris Comparison (One Charge)<br />
Mirage Case Debris<br />
LD Zinc Case Debris<br />
Steel Case Debris<br />
0.0<br />
> 0.500 > 0.375 > 0.250 > 0.187 > 0.094 > 0.066 > 0.033 > 0.011
Maxim Shaped Charges<br />
The completion of wells in unconsolidated formations<br />
generally requires some form of s<strong>and</strong> control or gravel<br />
packing for flow assurance. For a cased <strong>and</strong> perforated s<strong>and</strong><br />
control completion, the perforating strategy typically calls<br />
for perforations with the largest possible exit hole in the<br />
casing with as high a shot density (spf) as possible. The large<br />
casing exit hole improves the likelihood of placing s<strong>and</strong> or<br />
gravel into the perforation tunnel <strong>and</strong> the higher spf<br />
increases the effective flow area resulting in lower pressure<br />
drop across the completion during production.<br />
As completion targets in deep water environments go deeper,<br />
drilling challenges are compounded forcing operators in<br />
many cases to set the casing shoe point higher than planned<br />
in order to safely reach deeper primary targets.<br />
Unfortunately, this scenario results in secondary pay zones<br />
that have multiple strings of casing across portions or the<br />
entire length of the pay zone. This situation presents a<br />
serious technical challenge because the typical big-hole (BH)<br />
perforating system cannot efficiently penetrate multiple<br />
casing strings <strong>and</strong> still produce an adequate casing exit hole.<br />
The results utilizing conventional BH perforating systems in<br />
the past yielded a large exit hole in the first casing string <strong>and</strong><br />
a very small exit hole in the second casing string with<br />
minimal formation penetration.<br />
Revolutionary Shaped Charge Liner Design Meets the<br />
Challenge<br />
Shaped charge design engineers at <strong>Halliburton</strong>'s Jet Research<br />
Center (JRC) have unleashed the power of Maxim shaped<br />
charges by utilizing hydro-code modeling software <strong>and</strong> flash<br />
X-ray imaging to develop a proprietary shaped charge liner<br />
that optimizes the casing exit-hole size when penetrating<br />
multiple casing strings.<br />
The effectiveness of the new Maxim shaped charge concept<br />
was demonstrated with the development of a 5-in. 8 spf<br />
47 gram charge for a completion scenario with 7-5/8-in.<br />
47.1 lb/ft P-110 <strong>and</strong> 9-5/8-in. 47 lb/ft P-110 casing.<br />
A st<strong>and</strong>ard 5-in. 12 spf 28 gram BH gun system was tested<br />
under the completion configuration described resulting in a<br />
casing exit-hole of 0.28-in.<br />
Charge Part<br />
No.<br />
Gun OD SPF<br />
The newly developed Maxim perforating system resulted in a<br />
casing exit-hole size of 0.66-in. with an impressive formation<br />
penetration of 6.0-in. These results show a significant 136%<br />
improvement in casing exit-hole size <strong>and</strong> 270%<br />
improvement in flow area on a per foot basis.<br />
HAL15955 Maxim Dual String Technology<br />
Maxim Charge Performance Data<br />
Explosive<br />
Load<br />
Existing Dual String<br />
Technology<br />
Exp<strong>and</strong>ing<br />
Case Fragments<br />
Stretching Jet<br />
Jet Tip<br />
Rearmost Portion<br />
of Jet<br />
<strong>Perforating</strong> Solutions 5-5<br />
HAL16359<br />
Flash X-ray <strong>and</strong> hydro-code simulation of a shaped charge during<br />
detonation sequence.<br />
Inner Casing Exit Hole Outer Casing Exit Hole Penetration*<br />
101350449 5.00 8 47 7 5/8 47.1# P-110 0.75 9 5/8 47 P-110 0.66 6.00<br />
101357518 5.75 10 56.5 8 5/8 60.8# P-110 0.78 11 3/4 65# P-110 0.63 7.50<br />
101357518 7.00 14 56.5 9 5/8 473 lL-80 0.61 13 3/8 72# P-110 0.68 8.77<br />
*Penetration is in cement measured from the OD of the outer casing.<br />
HAL16362
KISS Low-Damage <strong>Perforating</strong> Charge<br />
The KISS charge provides all the benefits expected from<br />
big-hole charges—yet produces significantly less damage in<br />
unconsolidated formations.<br />
KISS charges limit perforating damage with minimal<br />
penetrator design charges, reducing damaged material eightfold.<br />
Damaged material is near the casing with 200% of the<br />
cross-sectional area a possibility. Penetration past the cement<br />
is not a problem, <strong>and</strong> lower explosive weight charges are less<br />
susceptible to carrier failure.<br />
In an extensive series of lab tests comparing KISS lowdamage<br />
charges with conventional big-hole perforating<br />
charges under simulated downhole conditions, the KISS<br />
charge more than proved its superiority. In these tests:<br />
KISS charges created holes in the casing that were equal<br />
to or larger in diameter than those created by<br />
conventional big-hole perforating charges.<br />
Perforation depth was appropriately reduced, so there<br />
was far less damage to the formation as well as a<br />
significantly reduced crushed zone (less than 1/3 of a<br />
conventional big-hole charge).<br />
KISS charges easily penetrated 2-in. thick cement<br />
sheaths, proving they can be effective even in wellbores<br />
where washouts have occurred.<br />
Less damage occurred to the cement surrounding the<br />
entrance hole, <strong>and</strong> the cement damage area was smaller.<br />
Features<br />
Can be run in st<strong>and</strong>ard VannGun® perforating guns <strong>and</strong><br />
conveyed on tubing or wireline<br />
Complements <strong>Halliburton</strong>’s StimGun service by<br />
producing an instantaneous, high-pressure surge into<br />
the formation to enhance perforating <strong>and</strong> stimulation<br />
results<br />
Specialists help determine if the KISS low damage<br />
perforating charge would be a productive choice for a<br />
specific well<br />
Low impact on unconsolidated formations for a positive<br />
impact on completions<br />
Better gravel packs due to greatly improved fluid<br />
injectivity—whether running a conventional gravel pack,<br />
a FracPac system, or a high-rate water pack<br />
Reduced fines movement<br />
Reduced s<strong>and</strong> production<br />
HAL5945<br />
The unique KISS perforating charge is designed to just penetrate the<br />
formation while the high pressure gas breaks through the crushed zone in<br />
the tunnel <strong>and</strong> creates fractures in the formation.<br />
5-6 <strong>Perforating</strong> Solutions
Gun Size Phasing JRC P/N Charge Name<br />
Charge Performance Data<br />
CAPSULE GUNS<br />
Explosive<br />
Load<br />
(Grams)<br />
Casing<br />
Size (in.)<br />
Target<br />
Strength<br />
(psi)<br />
EHD (in.)<br />
Total Target<br />
Penetration<br />
(in.)<br />
Penetration<br />
Normalized<br />
to 5000 psi<br />
(5% per<br />
1000)<br />
1-11/16” 0 100005450 1-11/16” Dyna-Star ® 4 SPF RDX DP 13.4 4-1/2” 5149 0.39 10.50 19B<br />
1-11/16” 0 100005450 1-11/16” Dyna-Star 4 SPF RDX DP 13.4 4-1/2” 5909 0.40 12.46 13.03 QC<br />
1-11/16” 0 100005449 1-11/16” Dyna-Star 6 SPF HMX DP 13.5 4-1/2” 6384 0.41 11.97 12.80 QC<br />
1-11/16” 0 101398891 1-11/16” MILLENNIUM Dyna-Star 6 SPF HMX 8 4-1/2” 5426 0.29 24.00 24.51 QC<br />
1-11/16” 0 101521848 1-11/16” MaxForce Deep Star 8 SPF HMX 8 4-1/2” 7170 0.27 19.90 19B<br />
2-1/8” 0 101210198 2-1/8” MILLENNIUM Deep Star HMX 15.9 5-1/2” 5435 0.40 30.60 31.27 QC<br />
2-1/8” 0 101383082 2-1/8” MILLENNIUM Dyna-Star 6 SPF HMX 15.9 5-1/2” 5633 0.39 29.07 29.99 QC<br />
2-1/8” 0 100008259 2-1/8” Dyna-Star 6 SPF HMX DP 15.5 5-1/2” 5326 0.38 14.84 15.08 QC<br />
2-1/8” 0 100005448 2-1/8” Dyna-Star 6 SPF RDX DP 15.5 5-1/2” 5538 0.42 16.61 17.06 RP43<br />
2-1/8” 0 100005448 2-1/8” Dyna-Star 4 SPF RDX DP 15.5 5-1/2” 5292 0.35 15.50 19B<br />
2-1/8” 90 101210198 2-1/8” MILLENNIUM Deep Star 4 SPF HMX DP 15.9 5-1/2” 5820 0.31 20.60 19B<br />
2-1/8” 0/45/90 101210198<br />
2-1/8” MILLENNIUM Deep Star 5.8 SPF HMX -<br />
PENTAPHASE Oscillating Spiral<br />
PORTED GUNS<br />
<strong>Perforating</strong> Solutions 5-7<br />
* Unofficial<br />
Data<br />
15.9 5-1/2” 6740 0.30 20.60 19B<br />
3-1/8” 90 101410556 3-1/8” GSC 4 SPF RDX DP 12 4-1/2” 5500 0.34 20.90 21.42 QC<br />
4” 90 101288857 4" MILLENNIUM EXPRESS GSC 19.5 5-1/2” 5600 0.51 27.18 27.95 QC<br />
SLICKWALL GUNS<br />
3-1/8” 60 / 90 101366678 3-1/8” MILLENNIUM IS 4 SPF HMX 21 4-1/2” 6200 0.40 38.30 40.60 QC<br />
3-1/8” 90 101204537 4” Basic MILLENNIUM EXPRESS 4 SPF RDX 19.5 5-1/2” 6277 0.50 16.65 17.71 QC<br />
4” 90 101204537 4” Basic MILLENNIUM EXPRESS 4 SPF RDX 19.5 5-1/2” 6277 0.50 24.94 26.53 QC<br />
3-1/8” 60 / 90 101310802<br />
4” 60 / 90 101310802<br />
4” Twisted Strip MILLENNIUM EXPRESS 4 SPF<br />
RDX W/ TWIST LOCK 1/2 RUBBER JACKET<br />
4” Twisted Strip MILLENNIUM EXPRESS 4 SPF<br />
RDX W/ TWIST LOCK 1/2 RUBBER JACKET<br />
SCALLOPED GUNS<br />
19.5 5-1/2” 6277 0.50 16.65 17.71 QC<br />
19.5 5-1/2” 6277 0.50 24.94 26.53 QC<br />
1-9/16” 0 100157028 1-9/16” MILLENNIUM IS 4 SPF HMX 3.4 4-1/2” 5967 0.21 11.34 11.89 RP43<br />
1-9/16” 60 100157028 1-9/16” MILLENNIUM IS 6 SPF HMX 3.4 2-7/8” 6949 0.23 8.30 19B<br />
1-9/16” 60 384465 1-9/16” 4 SPF HMX BH 3.2 2-7/8” 7533 0.34 2.50 19B<br />
2” 60 101208224 2” MILLENNIUM IS HMX 6.8 2-7/8” 6019 0.22 18.30 19B<br />
2” 60 101603801 2" MaxForce IS HMX 7 2-7/8” 5697 0.24 20.30 19B<br />
2” 60 101206246 2” IS 6 SPF-HMX BH 6.8 3-1/2” 7332 0.48 3.00 19B<br />
2-3/8” 60 101590845 2-3/8” MaxForce IS 6 SPF HMX 10 3-1/2” 5663 0.28 19.90 19B<br />
2-3/8” 60 101591373 2-3/8” 6 SPF HMX BH 10 3-1/2” 5663 0.48 5.80 19B<br />
2-1/2” 60 101418095 2 1/2” MILLENNIUM II IS 6 SPF HMX 11.1 3-1/2” 5996 0.32 24.50 19B<br />
2-1/2” 60 101244923 2-1/2” 6 SPF HNS DP 11.1 3-1/2' 7128 0.26 12.60 19B<br />
2-1/2” 60 384466 2-1/2” 6 SPF HMX BH 11 3-1/2' 7469 0.58 2.40 19B<br />
2-3/4” 60 101233817 2-3/4” MILLENNIUM 6 SPF HMX 15 4-1/2” 6394 0.30 26.00 19B<br />
2-3/4” 60 101318485 2-3/4” 6 SPF MILLENNIUM HNS 15.1 4-1/2” 5694 0.30 27.55 28.51 QC<br />
2-3/4” 60 101206793 2-3/4” 6 SPF RDX BH 14.7 4-1/2” 6109 0.67 5.50 5.80 RP43<br />
2-3/4” 60 101270158 2-3/4” 6 SPF HMX BH 15 4-1/2” 7381 0.65 4.20 19B<br />
2-7/8” 60 101233817 2-3/4” MILLENNIUM 6 SPF HMX (Hvy Wall Gun) 15 4-1/2” 6388 0.31 27.30 19B<br />
2-7/8” 60 101233817 2-3/4” MILLENNIUM 6 SPF HMX (Hvy Wall Gun) 15 4-1/2” 5124 0.35 30.00 19B 3<br />
2-7/8” 60 101388407 2-7/8” MILLENNIUM 6 SPF HNS 18.5 4-1/2” 6859 0.28 22.80 19B<br />
3-1/8” 60 101366678 3-1/8” MILLENNIUM IS 6 SPF HMX 21 4-1/2” 6200 0.40 38.30 40.60 QC
Gun Size Phasing JRC P/N Charge Name<br />
Charge Performance Data<br />
Explosive<br />
Load<br />
(Grams)<br />
Casing<br />
Size (in.)<br />
3-1/8” 60 101618998 3-1/8” MILLENNIUM Express IS DP 6 SPF RDX 21 4-1/2”<br />
3-1/8” 60 101618994 3-1/8” MILLENNIUM Express IS SDP 6 SPF RDX 21 4-1/2”<br />
Target<br />
Strength<br />
(psi)<br />
3-1/8” 135/45 101351605 3-1/8” Mirage ® 10 SPF HMX BH/LD 14 5” 6100 0.64 3.80 4.01 QC<br />
3-3/8” 60 101233819 3-3/8” MILLENNIUM 6 SPF HMX 25 4-1/2” 6215 0.48 40.40 42.85 RP43<br />
3-3/8” 60 101233819 3-3/8” MILLENNIUM 6 SPF HMX 25 4-1/2” 5754 0.45 37.50 19B<br />
3-3/8” 60 101600039 3-3/8” MILLENNIUM Express IS 6 SPF RDX DP 23 4-1/2” 5704 0.42 25.60 26.5 QC<br />
3-3/8” 60 101589595 3-3/8” MILLENNIUM Express IS 6 SPF RDX SDP 23 4-1/2” 5219 0.39 43.00 43.5 QC<br />
3-3/8” 60 101365876 3-3/8” MILLENNIUM 6 SPF HNS 25 4-1/2” 6578 0.31 22.10 19B<br />
3-3/8” 60 101320459 3-3/8” 6 SPF RDX DP 22 4-1/2” 7538 0.34 17.60 19B<br />
3-3/8” 60 100005333 3-3/8” 6 SPF RDX DP 22 4-1/2” 6138 0.41 20.30 21.46 RP43<br />
3-3/8” 60 100005332 3-3/8” 6 SPF HMX DP 26 5-1/2” 9846 0.38 18.28 22.71 RP43<br />
3-3/8” 60 100008014 3-3/8” 6 SPF RDX SUPER DP 24 4-1/2” 5251 0.39 28.45 28.81 RP43<br />
3-3/8” 60 100008249 3-3/8” 6 SPF HMX SUPER DP 25 4-1/2” 5967 0.40 26.20 19B<br />
3-3/8” 60 100008249 3-3/8” 6 SPF HMX SUPER DP 25 5” 6097 0.40 28.70 30.27 RP43<br />
3-3/8” 135/45 101351605 3-3/8” Mirage 12 SPF HMX BH/LD 14 5-1/2” 6100 0.63 4.15 4.38 QC<br />
3-3/8” 60 100005321 3-3/8” 6 SPF RDX BH 24 4-1/2” 6101 0.86 4.66 4.92 QC<br />
3-3/8” 60 100157017 3-3/8” 6 SPF HMX BH 24 4-1/2” 6490 0.88 4.76 5.11 QC<br />
3-3/8” 150/30 100008251 3-3/8” Omni 12 SPF RDX BH 14 5-1/2” 7802 0.62 5.33 6.08 RP43<br />
3-3/8” 150/30 100005312 3-3/8” Omni 12 SPF HMX BH 14 5-1/2” 6300 0.64 5.24 5.58 QC<br />
3-1/2” 135/45 101542642 3-1/2” Mirage 12 SPF HMX BH/LD 15 5-1/2” 6100 0.65 4.20 4.43 QC<br />
4” 90 101210636 4” MILLENNIUM HMX (4 SPF) 39 5-1/2” 5490 0.39 44.60 45.69 RP43<br />
4” 90 101210636 4” MILLENNIUM HMX (4 SPF) 39 5-1/2” 6365 0.38 43.40 19B<br />
4” 60 100005322 4-5/8” 6 SPF RDX DP 32 7” 5277 0.6 40.50 41.06 QC<br />
4” 60 100005327 4-5/8” 6 SPF HMX DP 32 5-1/2” 5568 0.45 37.00 19B 4<br />
4-1/2” 60 101210636 4” MILLENNIUM HMX (5 SPF) 39 7” 6775 0.37 39.60 19B<br />
4-1/2” 150/30 101210674 4-1/2” MILLENNIUM 12 SPF HMX 22.7 7” 8484 0.38 26.80 31.47 RP43<br />
4-5/8” 180 101446899 4-5/8” KleenZone ® G-FORCE ® HMX 39 7" 5208 0.36 42.80 19B<br />
4-5/8” 350/10 101446899 4-5/8” KleenZone G-FORCE HMX 39 7" 5412 0.35 41.70 19B<br />
4-5/8” 60 101210636 4” MILLENNIUM HMX (5 SPF) 39 7” 5502 0.37 52.00 53.31 RP43<br />
4-5/8” 60 101210636 4” MILLENNIUM HMX (5 SPF) 39 7” 5518 0.35 43.60 19B<br />
4-5/8” 60 101287306 4” 5 SPF HNS DP 39 7” 7559 0.33 31.20 19B<br />
4-5/8” 60 100005322 4-5/8” 6 SPF RDX DP 32 7” 5325 0.43 30.46 30.95 RP43<br />
4-5/8” 60 100005327 4-5/8” 6 SPF HMX DP 32 7” 5809 0.46 39.50 41.10 QC<br />
4-5/8” 60 101332806 4-5/8” 6 SPF HNS DP 32 7” 5814 0.45 30.30 31.53 QC<br />
4-5/8” 150/30 101210674 4-1/2” MILLENNIUM 12 SPF HMX 22.7 7” 8484 0.38 26.80 31.47 RP43<br />
4-5/8” 150/30 101210674 4-1/2” MILLENNIUM 12 SPF HMX 22.7 7” 6322 0.38 24.40 19B<br />
4-5/8” 150/30 100005324 4-5/8” Omni 12 SPF RDX DP 22.7 7” 9080 0.36 16.25 19.57 RP43<br />
4-5/8” 150/30 100005325 4-5/8” Omni 12 SPF RDX DP/LD 22.7 7” 5685 0.32 17.41 18.01 RP43<br />
4-5/8” 150/30 100014352 4-5/8” Omni 12 SPF HMX DP 22.7 7” 9080 0.37 16.09 19.37 RP43<br />
4-5/8” 150/30 101343830 4-5/8” Omni 12 SPF HNS DP 7” 5020 0.35 28.00 28.03 QC<br />
4-5/8” 150/30 100005340 4-5/8” Omni 12 SPF HMX DP/LD 22.7 7” 5685 0.30 18.37 19.00 RP43<br />
4-5/8” 150/30 100005319 4-5/8” Omni 12 SPF RDX BH 25 7” 6840 0.74 6.41 7.00 RP43<br />
4-5/8” 150/30 100005326 4-5/8” Omni 12 SPF RDX BH/LD 22.7 7” 7346 0.65 5.51 6.16 RP43<br />
4-5/8” 150/30 100157006 4-5/8” 12 SPF HMX BH 25 7” 5723 0.75 7.02 7.27 QC<br />
4-5/8” 150/30 100005311 4-5/8” Omni 12 SPF RDX SH 28 7” 6982 0.93 6.30 6.92 RP43<br />
4-5/8” 150/30 100156995 4-5/8” Omni 12 SPF HMX SH 28 7” 5016 0.96 5.10 5.10 RP43<br />
EHD (in.)<br />
Total Target<br />
Penetration<br />
(in.)<br />
Penetration<br />
Normalized<br />
to 5000 psi<br />
(5% per<br />
1000)<br />
5-8 <strong>Perforating</strong> Solutions<br />
* Unofficial<br />
Data
Gun Size Phasing JRC P/N Charge Name<br />
4-5/8” 150/30 101228756 4-5/8” 12 SPF RDX SUPER HOLE/LD 28 7” 5124 0.81 5.40 5.43 QC<br />
4-5/8” 150/30 101233690 4-5/8” 12 SPF HMX SUPER HOLE/LD 28 7” 5622 0.85 5.30 5.46 RP43<br />
4-5/8” 135/45 100156990 4-5/8” 18 SPF RDX BH 20 7” 5553 0.73 6.18 6.35 RP43<br />
4-5/8” 180 101287306 4-5/8” 4 SPF HNS DP 39 7-5/8” 6349 0.29 30.20 19B<br />
5” 150/30 100005311 4-5/8” Omni 12 SPF RDX SUPER HOLE 28 7” 5192 0.91 6.90 6.97 RP43<br />
5” 150/30 100005319 4-5/8” Omni 12 SPF RDX BH 25 7” 6508 0.84 8.80 9.46 QC<br />
5” 150/30 100156995 4-5/8” Omni 12 SPF HMX SUPER HOLE 28 7” 6487 1.00 6.00 6.45 QC<br />
5” 150/30 100005311 4-5/8” Omni 12 SPF RDX SUPER HOLE 28 7-5/8” 7877 0.83 6.65 7.61 RP43<br />
5” 135 101307494 5" Mirage ® 12 SPF RDX SUPER HOLE/LD 32 7-5/8” 6345 0.90 6.00 19B<br />
5”<br />
120<br />
Cluster<br />
101292616 5" 21 SPF RDX BH 21 7-5/8” 5411 0.72 5.30 19B 1<br />
5-1/8” 135 101307494 5" Mirage 12 SPF RDX SUPER HOLE/LD 32 7-5/8” 5576 0.88 6.60 19B<br />
5-1/8” 231.4 100157007 5-1/8” 14 SPF RDX SUPER HOLE 32 7-5/8” 5138 0.93 5.11 5.15 RP43<br />
5-1/8” 231.4 100157011 5-1/8” 14 SPF HMX SUPER HOLE 32 7-5/8” 5250 0.94 5.83 5.90 RP43<br />
5-1/8”<br />
120<br />
Cluster<br />
101292616 5-1/8” 21 SPF RDX BH 21 7-5/8” 6246 0.74 5.65 5.99 QC<br />
5-3/4” 150/30 100157007 5-1/8” 14 SPF RDX SUPER HOLE 32 8-5/8” 6498 0.75 5.87 6.31 QC<br />
6-1/2”<br />
6-1/2”<br />
135/45<br />
138<br />
135/45<br />
138<br />
101304878 6-1/2” Mirage 12 or 14 SPF RDX BH/LD 47 8-5/8” 7043 1.07 5.60 19B<br />
101304878 6-1/2” Mirage 12 or 14 SPF RDX BH/LD 47 9-5/8” 5088 0.91 6.80 19B 2<br />
7” 135/45 101207997 7” MILLENNIUM 12 SPF HMX 39 9-5/8” 7006 0.36 43.30 47.63 RP43<br />
7” 135/45 101207997 7” MILLENNIUM 12 SPF HMX 39 9-5/8” 6397 0.42 38.70 19B<br />
7”<br />
7”<br />
7”<br />
135/45<br />
138<br />
135/45<br />
138<br />
135/45<br />
138<br />
101304878 6-1/2” Mirage 12 or 14 SPF RDX BH/LD 47 9-5/8” 6178 1.07 6.10 19B<br />
101213474 7” 12 or 14 SPF RDX SUPER HOLE 56.5 9-5/8” 5975 1.29 5.80 19B<br />
101484232 7” Mirage 14 SPF RDX BH/LD 39 9-5/8” 6270 1.04 6.30 19B<br />
7” 138 101212693 7” 12 SPF RDX SUPER HOLE/LD 56.5 9-5/8” 6040 1.16 5.00 19B<br />
7” 60/120 101414821 7” Mirage 18 SPF HMX/LD 45 9-7/8” 5893 1.02 6.50 19B<br />
Registered 19B data except fired in 7-5/8” 47# P110 casing<br />
Registered 19B data except fired in 9-5/8” 71# N-80 casing<br />
Registered 19B data except fired in air<br />
Registered third party 19B data<br />
MaxForce, G-Force ® ,<strong>and</strong> KleenZone ® are proprietary to <strong>Halliburton</strong><br />
Charge performance will vary due to well conditions.<br />
For realistic data, contact JRC “Perforation Flow Lab” testing services.<br />
Penetration normalization is not certified by API for 19B.<br />
RP43 Test are not endorsed by API <strong>and</strong> will not be available on new or improved JRC Charges.<br />
Charge Performance Data<br />
Explosive<br />
Load<br />
(Grams)<br />
Casing<br />
Size (in.)<br />
Target<br />
Strength<br />
(psi)<br />
EHD (in.)<br />
Total Target<br />
Penetration<br />
(in.)<br />
Penetration<br />
Normalized<br />
to 5000 psi<br />
(5% per<br />
1000)<br />
<strong>Perforating</strong> Solutions 5-9<br />
* Unofficial<br />
Data
Gun Systems<br />
VannGun ® Assemblies<br />
1 9/16 in. to 7 in. <strong>and</strong> 4 SPF to 21 SPF<br />
5-10 <strong>Perforating</strong> Solutions<br />
7.00"<br />
6.50"<br />
6.00"<br />
5.75"<br />
5.125"<br />
5.00"<br />
4.75"<br />
4.625"<br />
4.50"<br />
4.25"<br />
4.00"<br />
3.375"<br />
3.125"<br />
2.875"<br />
2.75"<br />
2.50"<br />
2.00"<br />
1.563”
VannGun ® Phasing <strong>and</strong> Shot Patterns*<br />
0° Phasing 4 <strong>and</strong> 5 SPF<br />
HAL10590<br />
60° Phasing 4, 5, <strong>and</strong> 6 SPF<br />
HAL15978<br />
*Other shot densities <strong>and</strong> phasings are available upon request.<br />
6"<br />
6"<br />
12"<br />
0º 180º 360º<br />
6"<br />
6"<br />
12"<br />
4 SPF<br />
4 SPF<br />
0º 60º 120º 180º 240° 300º 360º<br />
<strong>Perforating</strong> Solutions 5-11<br />
6"<br />
6"<br />
12"<br />
6"<br />
6"<br />
12"<br />
5 SPF<br />
0º 180º 360º<br />
6"<br />
6"<br />
12"<br />
6 SPF<br />
0º 60º 120º 180º 240° 300º 360º<br />
5 SPF<br />
0º 60º 120º 180º 240° 300º 360º
90° Phasing 4 SPF<br />
180° Phasing 4 <strong>and</strong> 8 SPF<br />
HAL15982<br />
HAL15981<br />
6"<br />
6"<br />
12"<br />
4 SPF<br />
5-12 <strong>Perforating</strong> Solutions<br />
6"<br />
6"<br />
12"<br />
0º 180º 360º<br />
4 SPF<br />
0º 90º 180º 270° 360º<br />
6"<br />
6"<br />
12"<br />
8 SPF<br />
0º 180º 360º
60° Phasing 6 SPF Two Planes<br />
45°/135° Phasing 5, 6, 8, 12, <strong>and</strong> 18 SPF<br />
6"<br />
6"<br />
12"<br />
HAL15355<br />
8 SPF<br />
HAL15356<br />
0º 45º 90º 135º 180º 225° 270º 315º 360º<br />
6"<br />
6"<br />
12"<br />
6"<br />
6"<br />
12"<br />
6"<br />
6"<br />
12"<br />
5 SPF<br />
0º 45º 90º 135º 180º 225° 270º 315º 360º<br />
12 SPF<br />
0º 102.9° 205.7° 308.6°<br />
51.4° 154.3° 257.1° 360º<br />
0º 45º 90º 135º 180º 225° 270º 315º 360º<br />
<strong>Perforating</strong> Solutions 5-13<br />
6 SPF<br />
6"<br />
6"<br />
12"<br />
6"<br />
6"<br />
12"<br />
6 SPF<br />
0º 45º 90º 135º 180º 225° 270º 315º 360º<br />
18 SPF<br />
0º 45º 90º 135º 180º 225° 270º 315º 360º
140°/160° Phasing 11 SPF<br />
HAL15983<br />
51.4°/154.3° Phasing 12 SPF<br />
30°/150° Phasing 12 SPF<br />
HAL15354<br />
HAL15357<br />
5-14 <strong>Perforating</strong> Solutions<br />
6"<br />
6"<br />
12"<br />
6"<br />
6"<br />
12"<br />
6"<br />
6"<br />
12"<br />
0º<br />
100º<br />
11 SPF<br />
180° 260° 360°<br />
110º 250°<br />
12 SPF<br />
0º 102.9° 205.7° 308.6°<br />
51.4° 154.3° 257.1° 360º<br />
12 SPF<br />
0º 60° 120º 180º 240° 300º 360°<br />
30º 90º 150° 210° 270º 330°
25.7°/128.5° Phasing 14 SPF<br />
60°/120° Phasing 18 <strong>and</strong> 21 SPF<br />
HAL15984<br />
138° Phasing 14 SPF<br />
HAL15993<br />
HAL15985<br />
6"<br />
6"<br />
12"<br />
6"<br />
6"<br />
12"<br />
18 SPF<br />
0º 60º 120º 180º 240° 300º 360º<br />
6"<br />
6"<br />
12"<br />
14 SPF<br />
0º 51º 103º 154º 206º 257° 309º 360º<br />
26º 77º 129º 180º 231º 283° 334º<br />
<strong>Perforating</strong> Solutions 5-15<br />
6"<br />
6"<br />
12"<br />
14 SPF<br />
0º 45º 90º 135º 180º 225° 270º 315º 360º<br />
21 SPF<br />
0º 60º 120º 180º 240° 300º 360º
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Tensile ratings on the following tables are based on the box x pin connection.<br />
Charge<br />
Type<br />
1 9/16-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
Pressure<br />
Rating<br />
psi (bar)<br />
100157028 HMX Millennium 4 0° Premium Vann 20,000<br />
(1379)<br />
101210199 HMX BH 60°<br />
90°<br />
180°<br />
0° Premium Industry<br />
St<strong>and</strong>ard<br />
20,000<br />
(1379)<br />
100157028 HMX Millennium 6 60° Premium Vann 20,000<br />
(1379)<br />
60°<br />
90°<br />
180°<br />
101210199 HMX BH 60° Premium Industry<br />
St<strong>and</strong>ard<br />
20,000<br />
(1379)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
70,000<br />
(31 746)<br />
70,000<br />
(31 746)<br />
70,000<br />
(31 746)<br />
70,000<br />
(31 746)<br />
Weights<br />
5-16 <strong>Perforating</strong> Solutions<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
4 spf Millennium<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 21 (9) 17 (8)<br />
7 (2.13) 31 (14) 24 (11)<br />
11 (3.35) 46 (21) 34 (15)<br />
15 (4.57) 60 (27) 44 (20)<br />
21 (6.40) 81 (37) 59 (27)<br />
6 spf Millennium<br />
4 (1.22) 21 (10) 17 (8)<br />
7 (2.13) 32 (14) 24 (11)<br />
11 (3.35) 48 (22) 34 (15)<br />
15 (4.57) 63 (28) 44 (20)<br />
21 (6.40) 85 (39) 59 (27)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
2-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
101208224 HMX Millennium 4 0° Premium Vann<br />
101603801 HMX MaxForce<br />
100008017 HMX SDP<br />
100157018 HNS DP<br />
60°<br />
90°<br />
180°<br />
101206246 HMX BH 0° Premium<br />
60°<br />
90°<br />
180°<br />
Industry<br />
St<strong>and</strong>ard<br />
101208224 HMX Millennium 6 60° Premium Vann<br />
101603801 HMX MaxForce 60° Premium<br />
Industry<br />
St<strong>and</strong>ard<br />
Pressure<br />
Rating<br />
psi (bar)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
70,000<br />
(31 746)<br />
70,000<br />
(31 746)<br />
70,000<br />
(31 746)<br />
70,000<br />
(31 746)<br />
Weights<br />
<strong>Perforating</strong> Solutions 5-17<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
4 spf Millennium<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 28 (13) 23 (10)<br />
7 (2.13) 44 (20) 35 (16)<br />
11 (3.35) 66 (30) 51 (23)<br />
15 (4.57) 87 (39) 63 (29)<br />
21 (6.40) 120 (54) 92 (42)<br />
6 spf Millennium<br />
4 (1.22) 28 (13) 23 (10)<br />
100008017 HMX SDP 7 (2.13) 44 (20) 35 (16)<br />
100157018 HNS DP 11 (3.35) 66 (30) 51 (23)<br />
101206246 HMX BH 15 (4.57) 87 (39) 63 (29)<br />
101208224 HMX Millennium 6 60° Premium Vann<br />
101603801 HMX MaxForce 60° Premium<br />
Industry<br />
St<strong>and</strong>ard<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
70,000<br />
(31 746)<br />
70,000<br />
(31 746)<br />
21 (6.40) 120 (54) 92 (42)<br />
6 spf Reduced Swell Gas Gun<br />
2 (.61) 14 (6.3) 11 (4.9)<br />
100008017 HMX SDP 4 (1.22) 25 (11.3) 20 (9.1)<br />
100157018 HNS DP 5 (1.52) 31 (14) 24 (10.9)<br />
101206246 HMX BH 6 (1.83) 36 (16.3) 28 (12.7)<br />
7 (2.13) 42 (19) 32 (14.5)<br />
8 (2.44) 48 (21.7) 36 (16.3)<br />
9 (2.74) 53 (24) 40 (18.2)<br />
11 (3.35) 65 (29.5) 48 (21.8)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge Type SPF Phasing<br />
2 1/2-in. Premium VannGun ® Assemblies<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
101206251 HMX Millennium 4 0° Premium Vann<br />
101332418 HMX SDP<br />
101244923 HNS DP<br />
60°<br />
90°<br />
180°<br />
0° Premium<br />
60°<br />
90°<br />
180°<br />
Industry<br />
St<strong>and</strong>ard<br />
101418095 HMX Millennium II 6 60° Premium Vann<br />
60° Premium<br />
Industry<br />
St<strong>and</strong>ard<br />
101206251 HMX Millennium 6 60° Premium Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
121,000<br />
(54 875)<br />
121,000<br />
(54 875)<br />
121,000<br />
(54 875)<br />
121,000<br />
(54 875)<br />
121,000<br />
(54 875)<br />
Weights<br />
5-18 <strong>Perforating</strong> Solutions<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
4 spf Millennium<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 43 (20) 34 (15)<br />
7 (2.13) 67 (30) 52 (24)<br />
11 (3.35) 98 (44) 75 (34)<br />
15 (4.57) 129 (59) 98 (44)<br />
21 (6.40) 176 (80) 133 (60)<br />
6 spf Millennium II<br />
4 (1.22) 43 (20) 34 (15)<br />
7 (2.13) 67 (30) 52 (24)<br />
11 (3.35) 98 (44) 75 (34)<br />
15 (4.57) 129 (59) 98 (44)<br />
21 (6.40) 176 (80) 133 (60)<br />
6 spf Millennium<br />
101332418 HMX SDP 4 (1.22) 45 (20) 34 (15)<br />
101244923 HNS DP 60° Premium<br />
101418095 HMX Millennium II 6 60° Premium<br />
Industry<br />
St<strong>and</strong>ard<br />
Industry<br />
St<strong>and</strong>ard<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
121,000<br />
(54 875)<br />
121,000<br />
(54 875)<br />
7 (2.13) 70 (32) 52 (24)<br />
11 (3.35) 104 (47) 75 (34)<br />
15 (4.57) 133 (60) 98 (44)<br />
21 (6.4) 189 (86) 133 (60)<br />
6 spf Reduced Swell Gas Gun<br />
4 (1.22) 43 (20) 34 (15)<br />
7 (2.13) 67 (30) 52 (24)<br />
11 (3.35) 98 (44) 75 (34)<br />
15 (4.57) 129 (59) 98 (44)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
2 3/4-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
101233817 HMX Millennium 4 60° St<strong>and</strong>ard<br />
101318485 HNS Millennium 120° St<strong>and</strong>ard<br />
100157026 RDX SDP 6<br />
60° Two<br />
Row<br />
Gun Thread<br />
Industry<br />
St<strong>and</strong>ard<br />
Industry<br />
St<strong>and</strong>ard<br />
Premium Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
18,000<br />
(1241)<br />
18,000<br />
(1241)<br />
20,000<br />
(1379)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
116,700<br />
(52 934)<br />
116,700<br />
(52 934)<br />
134,000<br />
(60 771)<br />
Weights<br />
<strong>Perforating</strong> Solutions 5-19<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
4 spf Millennium<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 59 (27) 50 (23)<br />
5 (1.53) 74 (34) 63 (29)<br />
6 (1.83) 88 (40) 75 (34)<br />
7 (2.13) 95 (43) 79 (35)<br />
8 (2.44) 102 (46) 82 (37)<br />
9 (2.74) 115 (52) 93 (42)<br />
10 (3.05) 125 (57) 99 (45)<br />
11 (3.35) 134 (61) 105 (48)<br />
15 (4.57) 172 (83) 145 (66)<br />
21 (6.71) 241 (114) 193 (88)<br />
6 spf SDP<br />
100010399 HMX SDP 4 (1.22) 59 (27) 50 (23)<br />
101251723 HNS SDP<br />
60° Two<br />
Row<br />
St<strong>and</strong>ard Vann<br />
18,000<br />
(1241)<br />
116,700<br />
(52 934)<br />
8 (2.44) 102 (46) 82 (37)<br />
101206793 RDX BH 11 (3.35) 134 (61) 105 (48)<br />
101270158 HMX BH 16 (4.88) 183 (83) 145 (66)<br />
101233817 HMX Millennium 6 60° Premium Vann<br />
101318485 HNS Millennium 60° St<strong>and</strong>ard Vann<br />
60° St<strong>and</strong>ard<br />
Industry<br />
St<strong>and</strong>ard<br />
22,000<br />
(1517)<br />
18,000<br />
(1241)<br />
18,000<br />
(1241)<br />
134,000<br />
(60 771)<br />
116,700<br />
(52 934)<br />
116,700<br />
(52 934)<br />
22 (6.71) 252 (114) 193 (88)<br />
6 spf Millennium<br />
4 (1.22) 59 (27) 50 (23)<br />
7 (2.13) 95 (43) 79 (35)<br />
8 (2.44) 102 (46) 82 (37)<br />
11 (3.35) 134 (61) 105 (48)<br />
15 (4.57) 172 (83) 145 (66)<br />
16 (4.88) 183 (83) 145 (66)<br />
22 (6.71) 252 (114) 193 (88)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
2 7/8-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
101233817 HMX Millennium 6 60° Premium Vann<br />
101318485 HNS Millennium 60° Premium<br />
Industry<br />
St<strong>and</strong>ard<br />
101388406 HMX Millennium 6 60° Premium Vann<br />
101388407 HNS Millennium 60° Premium<br />
101414743 HMX Dominator ®<br />
Industry<br />
St<strong>and</strong>ard<br />
101233817 HMX Millennium 6 60° Premium Vann<br />
101318485 HNS Millennium 60° Premium<br />
Industry<br />
St<strong>and</strong>ard<br />
Pressure<br />
Rating<br />
psi (bar)<br />
22,000<br />
(1517)<br />
22,000<br />
(1517)<br />
25,000<br />
(1724)<br />
25,000<br />
(1724)<br />
25,000<br />
(1724)<br />
25,000<br />
(1724)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
142,000<br />
(64 399)<br />
142,000<br />
(64 399)<br />
142,000<br />
(64 399)<br />
142,000<br />
(64 399)<br />
142,000<br />
(64 399)<br />
142,000<br />
(64 399)<br />
Weights<br />
5-20 <strong>Perforating</strong> Solutions<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
6 spf Millennium<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 62 (28) 54 (24)<br />
8 (2.44) 106 (48) 86 (39)<br />
11 (3.35) 138 (63) 110 (50)<br />
16 (4.88) 186 (84) 150 (68)<br />
22 (6.71) 258 (117) 198 (90)<br />
6 spf Millennium II<br />
4 (1.22) 62 (28) 54 (24)<br />
8 (2.44) 106 (48) 86 (39)<br />
11 (3.35) 138 (63) 110 (50)<br />
16 (4.88) 186 (84) 150 (68)<br />
22 (6.71) 258 (117) 198 (90)<br />
6 spf Millennium Gas Gun<br />
4 (1.22) 64 (29) 55 (25)<br />
101414743 HMX Dominator 8 (2.44) 112 (51) 92 (42)<br />
11 (3.35) 148 (67) 120 (54)<br />
16 (4.88) 204 (93) 166 (75)<br />
22 (6.71) 281 (127) 221 (100)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
3 3/8-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
101320459 RDX DP 4 60° Premium Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
25,000<br />
(1724)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
238,000<br />
(107 937)<br />
Weights<br />
<strong>Perforating</strong> Solutions 5-21<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
4 spf DP<br />
Spacer<br />
lb (kg)<br />
90° 4 (1.22) 86 (39) 77 (35)<br />
180° 7 (2.44) 126 (57) 109 (50)<br />
60° St<strong>and</strong>ard Vann<br />
20,000<br />
(1379)<br />
218,000<br />
(98 883)<br />
8 (2.44) 144 (65) 125 (57)<br />
90° 11 (3.35) 187 (85) 160 (73)<br />
180° 15 (4.88) 240 (109) 205 (93)<br />
60° St<strong>and</strong>ard<br />
Industry<br />
St<strong>and</strong>ard<br />
100008014 RDX SDP 4 60° Premium Vann<br />
20,000<br />
(1379)<br />
218,000<br />
(98 883)<br />
16 (4.88) 256 (116) 219 (99)<br />
90° 21 (6.41) 329 (150) 277 (126)<br />
20,000<br />
(1379)<br />
218,000<br />
(98 883)<br />
22 (6.71) 361 (164) 290 (132)<br />
4 spf SDP <strong>and</strong> Millennium<br />
101293450 RDX SDP/LD 90° 4 (1.22) 86 (39) 77 (35)<br />
101233819 HMX Millennium 180° 7 (2.44) 126 (57) 109 (50)<br />
101365876 HNS Millennium 60° St<strong>and</strong>ard Vann<br />
101600039 RDX<br />
101589595 RDX<br />
Millennium<br />
Express<br />
Millennium<br />
Express<br />
20,000<br />
(1379)<br />
218,000<br />
(98 883)<br />
8 (2.44) 144 (65) 125 (57)<br />
90° 11 (3.35) 187 (85) 160 (73)<br />
180° 15 (4.88) 240 (109) 205 (93)<br />
60° St<strong>and</strong>ard<br />
Industry<br />
St<strong>and</strong>ard<br />
20,000<br />
(1379)<br />
218,000<br />
(98 883)<br />
16 (4.88) 256 (116) 219 (99)<br />
90° 21 (6.41) 329 (150) 277 (126)<br />
4 60° St<strong>and</strong>ard<br />
Industry<br />
St<strong>and</strong>ard<br />
20,000<br />
(1379)<br />
218,000<br />
(98 883)<br />
22 (6.71) 361 (164) 290 (132)<br />
6 spf DP<br />
4 (1.22) 86 (39) 77 (35)<br />
7 (2.44) 126 (57) 109 (50)<br />
8 (2.44) 144 (65) 125 (57)<br />
11 (3.35) 187 (85) 160 (73)<br />
15 (4.88) 240 (109) 205 (93)<br />
16 (4.88) 256 (116) 219 (99)<br />
21 (6.41) 329 (150) 277 (126)<br />
22 (6.71) 361 (164) 290 (132)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
101320459 RDX DP 6 60° Premium Vann<br />
100008014 RDX SDP 60° St<strong>and</strong>ard Vann<br />
101293450 RDX SDP/LD 60° St<strong>and</strong>ard<br />
101233819 HMX Millennium<br />
60° Two<br />
Row<br />
101309223 HMX Dominator ® 60° Two<br />
Row<br />
Industry<br />
St<strong>and</strong>ard<br />
Premium Vann<br />
St<strong>and</strong>ard Vann<br />
25,000<br />
(1724)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
25,000<br />
(1724)<br />
20,000<br />
(1379)<br />
238,000<br />
(107 955)<br />
218,000<br />
(98 883)<br />
218,000<br />
(98 883)<br />
238,000<br />
(107 955)<br />
218,000<br />
(98 883)<br />
6 spf SDP <strong>and</strong> Millennium<br />
4 (1.22) 86 (39) 77 (35)<br />
7 (2.44) 126 (57) 109 (50)<br />
8 (2.44) 144 (65) 125 (57)<br />
11 (3.35) 187 (85) 160 (73)<br />
101365876 HNS Millennium 15 (4.88) 240 (109) 205 (93)<br />
100005321 RDX BH 16 (4.88) 256 (116) 219 (99)<br />
100157017 HMX BH 21 (6.41) 329 (150) 277 (126)<br />
100008251 RDX BH 12<br />
100005312 HMX BH<br />
3 3/8-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
30°/150°<br />
OMNI<br />
30°/150°<br />
OMNI<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
Premium Vann<br />
St<strong>and</strong>ard Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
23,000<br />
(1586)<br />
20,000<br />
(1379)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
238,000<br />
(107 955)<br />
218,000<br />
(98 883)<br />
Weights<br />
22 (6.71) 365 (166) 290 (132)<br />
12 spf BH<br />
4 (1.22) 89 (40) 77 (35)<br />
101351605 HMX BH/LD 8 (2.44) 150 (68) 125 (57)<br />
11 (3.35) 197 (88) 160 (73)<br />
16 (4.88) 271 (123) 219 (99)<br />
22 (6.71) 365 (166) 290 (132)<br />
5-22 <strong>Perforating</strong> Solutions<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
Spacer<br />
lb (kg)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
100005322 RDX DP<br />
4-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
4 60°<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
Premium Vann<br />
100005327 HMX DP 60° St<strong>and</strong>ard Vann<br />
90°<br />
Pressure<br />
Rating<br />
psi (bar)<br />
20,000<br />
(1379)<br />
18,000<br />
(1241)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
278,000<br />
(126 077)<br />
240,387<br />
(109 038)<br />
Weights<br />
<strong>Perforating</strong> Solutions 5-23<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
4 spf DP<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 107 (49) 99 (45)<br />
101332806 HNS DP 90° 8 (2.44) 173 (78) 155 (70)<br />
100008014 RDX SDP 90° St<strong>and</strong>ard<br />
Industry<br />
St<strong>and</strong>ard<br />
18,000<br />
(1241)<br />
240,387<br />
(109 038)<br />
11 (3.35) 223 (101) 197 (89)<br />
101293450 RDX SDP/LD 16 (4.88) 297 (135) 267 (121)<br />
100008249 HMX SDP 22 (6.71) 404 (183) 351 (159)<br />
100005322 RDX DP 6 60° Premium Vann<br />
100005327 HMX DP 60° St<strong>and</strong>ard Vann<br />
101332806 HNS DP 60° St<strong>and</strong>ard<br />
Industry<br />
St<strong>and</strong>ard<br />
20,000<br />
(1379)<br />
18,000<br />
(1241)<br />
18,000<br />
(1241)<br />
278,000<br />
(126 077)<br />
240,387<br />
(109 038)<br />
240,387<br />
(109 038)<br />
4 spf SDP<br />
4 (1.22) 110 (50) 99 (45)<br />
8 (2.44) 179 (81) 155 (70)<br />
11 (3.35) 230 (104) 197 (89)<br />
16 (4.88) 309 (140) 267 (121)<br />
22 (6.71) 420 (191) 351 (159)<br />
6 spf DP<br />
4 (1.22) 111 (50) 99 (45)<br />
8 (2.44) 189 (86) 155 (70)<br />
100008014 RDX SDP 11 (3.35) 233 (106) 197 (89)<br />
101293450 RDX SDP/LD 16 (4.88) 319 (144) 267 (121)<br />
100008249 HMX SDP 22 (6.71) 424 (192) 351 (159)<br />
6 spf SDP<br />
4 (1.22) 114 (52) 99 (45)<br />
8 (2.44) 189 (86) 155 (70)<br />
11 (3.35) 244 (111) 197 (89)<br />
16 (4.88) 336 (152) 267 (121)<br />
22 (6.71) 448 (203) 351 (159)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge Type SPF Phasing<br />
4 1/2-in. Premium VannGun ® Assemblies<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
101355271 RDX DP 5 60° St<strong>and</strong>ard Vann<br />
101210636 HMX Millennium 60° St<strong>and</strong>ard<br />
Industry<br />
St<strong>and</strong>ard<br />
Pressure<br />
Rating<br />
psi (bar)<br />
18,000<br />
(1241)<br />
18,000<br />
(1241)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
240,387<br />
(109 038)<br />
240,387<br />
(109 038)<br />
Weights<br />
5-24 <strong>Perforating</strong> Solutions<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
5 spf SDP<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 107 (49) 99 (45)<br />
101287306 HNS DP 8 (2.44) 173 (78) 155 (70)<br />
101356077 HNS Dominator ® 11 (3.35) 223 (101) 197 (89)<br />
101293450 RDX SDP/LD 6 60° St<strong>and</strong>ard Vann<br />
100008249 HMX SDP 60° St<strong>and</strong>ard<br />
Industry<br />
St<strong>and</strong>ard<br />
18,000<br />
(1241)<br />
18,000<br />
(1241)<br />
240,387<br />
(109 038)<br />
240,387<br />
(109 038)<br />
16 (4.88) 297 (135) 267 (121)<br />
22 (6.71) 404 (183) 351 (159)<br />
6 spf DP<br />
4 (1.22) 111 (50) 99 (45)<br />
100005322 RDX DP 7 (2.44) 126 (57) 109 (50)<br />
100005327 HMX DP 11 (3.35) 233 (106) 197 (89)<br />
101332806 HNS DP 15 (4.88) 240 (109) 205 (93)<br />
100008014 RDX SDP 21 (6.41) 329 (150) 277 (126)<br />
101233819 HMX Millennium<br />
101293450 RDX SDP/LD<br />
101262511 HNS SDP<br />
100008249 HMX SDP<br />
100005319 RDX BH 12 45°/135° St<strong>and</strong>ard Vann<br />
100005324 RDX DP 45°/135° St<strong>and</strong>ard<br />
Industry<br />
St<strong>and</strong>ard<br />
18,000<br />
(1241)<br />
18,000<br />
(1241)<br />
240,387<br />
(109 038)<br />
240,387<br />
(109 038)<br />
12 spf SDP<br />
4 (1.22) 111 (50) 99 (45)<br />
100005325 RDX DP/LD 7 (2.44) 126 (57) 109 (50)<br />
100005340 HMX DP/LD 11 (3.35) 233 (106) 197 (89)<br />
100014352 HMX DP 15 (4.88) 240 (109) 205 (93)<br />
100157006 HMX BH 21 (6.41) 329 (150) 277 (126)<br />
101210674 HMX Millennium
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
4 5/8-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
101210636 HMX Millennium 5 60° Premium Vann<br />
101287306 HNS Millennium 60° St<strong>and</strong>ard Vann<br />
100005322 RDX DP 6 60° Premium Vann<br />
100005327 HMX DP 60° St<strong>and</strong>ard Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
20,000<br />
(1379)<br />
19,000<br />
(1310)<br />
20,000<br />
(1379)<br />
19,000<br />
(1310)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
414,000<br />
(187 755)<br />
385,000<br />
(174 633)<br />
414,000<br />
(187 755)<br />
385,000<br />
(174 633)<br />
Weights<br />
<strong>Perforating</strong> Solutions 5-25<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
5 spf 39 g Millennium<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 156 (71) 135 (61)<br />
8 (2.44) 257 (117) 208 (94)<br />
11 (3.35) 333 (151) 265 (120)<br />
16 (4.88) 447 (203) 357 (162)<br />
22 (6.71) 611 (277) 469 (213)<br />
6 spf 32 g DP<br />
4 (1.22) 147 (67) 134 (61)<br />
101332806 HNS DP 8 (2.44) 235 (107) 207 (94)<br />
100008014 RDX SDP 11 (3.35) 301 (137) 262 (119)<br />
101293450 RDX SDP/LD 16 (4.88) 405 (184) 354 (161)<br />
100008249 HMX SDP 22 (6.71) 544 (247) 464 (210)<br />
100005311 RDX SH 8 45°/135° Premium Vann<br />
101228756 RDX SH/LD 45°/135° St<strong>and</strong>ard Vann<br />
20,000<br />
(1379)<br />
19,000<br />
(1310)<br />
414,000<br />
(187 755)<br />
385,000<br />
(174 633)<br />
8 spf SH<br />
4 (1.22) 151 (69) 134 (61)<br />
100156995 HMX SH 8 (2.44) 245 (111) 207 (94)<br />
101233690 HMX SH/LD 11 (3.35) 316 (143) 262 (119)<br />
16 (4.88) 420 (191) 353 (160)<br />
22 (6.71) 574 (260) 462 (210)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
4 5/8-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
100005319 RDX BH 11 140°/160° Premium Vann<br />
100005326 RDX BH/LD 140°/160° St<strong>and</strong>ard Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
16,000<br />
(1103)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
Weights<br />
5-26 <strong>Perforating</strong> Solutions<br />
14,000<br />
(965)<br />
414,000<br />
(187 755)<br />
385,000<br />
(174 633)<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
11 spf BH<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 153 (69) 129 (59)<br />
100157006 HMX BH 8 (2.44) 252 (114) 197 (89)<br />
120038060 HMX BH/LD 11 (3.35) 326 (148) 248 (112)<br />
100005324 RDX DP 16 (4.88) 438 (199) 334 (151)<br />
100014352 HMX DP 22 (6.71) 600 (272) 436 (198)<br />
101210674 HMX Millennium<br />
101343830 HNS DP<br />
100005324 RDX DP 12<br />
100005325 RDX DP/LD<br />
30°/150°<br />
OMNI<br />
30°/150°<br />
OMNI<br />
Premium Vann<br />
St<strong>and</strong>ard Vann<br />
20,000<br />
(1379)<br />
19,000<br />
(1310)<br />
414,000<br />
(187 755)<br />
385,000<br />
(174 633)<br />
12 spf Millennium<br />
4 (1.22) 158 (72) 127 (58)<br />
100014352 HMX DP 8 (2.44) 262 (119) 194 (88)<br />
100005340 HMX DP/LD 11 (3.35) 340 (154) 244 (111)<br />
101210674 HMX Millennium 16 (4.88) 459 (208) 327 (148)<br />
101343830 HNS DP 22 (6.71) 626 (284) 427 (194)<br />
100005319 RDX BH 12 spf BH<br />
100005326 RDX BH/LD 4 (1.22) 154 (70) 127 (58)<br />
100157006 HMX BH 8 (2.44) 254 (115) 194 (88)<br />
120038060 HMX BH/LD 11 (3.35) 328 (149) 244 (111)<br />
100005311 RDX SH 16 (4.88) 442 (200) 327 (148)<br />
101228756 RDX SH/LD 22 (6.71) 602 (273) 427 (194)<br />
100156995 HMX SH 12 spf SH<br />
101233690 HMX SH/LD 4 (1.22) 150 (68) 127 (58)<br />
8 (2.44) 245 (111) 194 (88)<br />
11 (3.35) 315 (143) 244 (111)<br />
16 (4.88) 422 (191) 327 (148)<br />
22 (6.71) 575 (261) 427 (194)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
100005311 RDX SH 14<br />
100156995 HMX SH<br />
4 5/8-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
25.7°/<br />
128.5°<br />
25.7°/<br />
128.5°<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
Premium Vann<br />
St<strong>and</strong>ard Vann<br />
100156990 RDX BH 18 45°/135° Premium Vann<br />
100157005 HMX DP 45°/135° St<strong>and</strong>ard Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
20,000<br />
(1379)<br />
19,000<br />
(1310)<br />
20,000<br />
(1379)<br />
19,000<br />
(1310)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
414,000<br />
(187 755)<br />
385,000<br />
(174 633)<br />
414,000<br />
(187 755)<br />
385,000<br />
(174 633)<br />
14 spf SH<br />
4 (1.22) 150 (68) 124 (56)<br />
8 (2.44) 244 (111) 188 (85)<br />
11 (3.35) 315 (143) 235 (107)<br />
16 (4.88) 422 (192) 314 (142)<br />
22 (6.71) 575 (261) 410 (186)<br />
<strong>Perforating</strong> Solutions 5-27<br />
Length<br />
ft (m)<br />
Weights<br />
Loaded<br />
lb (kg)<br />
18 spf<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 139 (63) 118 (54)<br />
8 (2.44) 222 (101) 176 (80)<br />
11 (3.35) 285 (129) 219 (99)<br />
16 (4.88) 379 (172) 291 (132)<br />
22 (6.71) 513 (233) 378 (171)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
100005324 RDX DP 12<br />
100005325 RDX DP/LD<br />
4 3/4-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
30°/150°<br />
OMNI<br />
30°/150°<br />
OMNI<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
Premium Vann<br />
St<strong>and</strong>ard Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
21,000<br />
(1447)<br />
19,000<br />
(1310)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
516,000<br />
(234 014)<br />
480,000<br />
(217 724)<br />
Weights<br />
5-28 <strong>Perforating</strong> Solutions<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
12 spf BH<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 169 (77) 144 (65)<br />
100014352 HMX DP 8 (2.44) 284 (129) 228 (103)<br />
100005340 HMX DP/LD 11 (3.35) 370 (168) 291 (132)<br />
101210674 HMX Millennium 16 (4.88) 505 (229) 395 (179)<br />
101343830 HNS DP 22 (6.71) 685 (311) 521 (236)<br />
100005319 RDX BH 12 spf DP<br />
100005326 RDX BH/LD 4 (1.22) 166 (75) 144 (65)<br />
100157006 HMX BH 8 (2.44) 277 (126) 228 (103)<br />
120038060 HMX BH/LD 11 (3.35) 361 (164) 291 (132)<br />
100005311 RDX SH 16 (4.88) 491 (223) 395 (179)<br />
101228756 RDX SH/LD 22 (6.71) 666 (302) 521 (236)<br />
100156995 HMX SH 12 spf Millennium<br />
101233690 HMX SH/LD 4 (1.22) 173 (78) 144 (65)<br />
8 (2.44) 292 (132) 228 (103)<br />
11 (3.35) 381 (173) 291 (132)<br />
16 (4.88) 522 (237) 395 (179)<br />
22 (6.71) 709 (321) 521 (236)<br />
12 spf SH<br />
4 (1.22) 165 (75) 144 (65)<br />
8 (2.44) 275 (125) 228 (103)<br />
11 (3.35) 357 (162) 291 (132)<br />
16 (4.88) 485 (220) 395 (179)<br />
22 (6.71) 657 (298) 521 (236)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
5-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
Pressure<br />
Rating<br />
psi (bar)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
Weights<br />
<strong>Perforating</strong> Solutions 5-29<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
101321963 RDX Maxim 6 45°/135° Premium Vann 6 spf SH<br />
101350449 RDX Maxim 8 45°/135° Premium Vann<br />
100005311 RDX SH 12<br />
30°/150°<br />
OMNI<br />
Premium Vann<br />
20,000<br />
(1379)<br />
18,000<br />
(1241)<br />
427,000<br />
(193 651)<br />
427,000<br />
(193 651)<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 175 (79) 152 (69)<br />
8 (2.44) 280 (127) 230 (104)<br />
11 (3.35) 359 (163) 288 (131)<br />
16 (4.88) 490 (222) 385 (175)<br />
22 (6.71) 648 (294) 502 (228)<br />
12 spf SH<br />
4 (1.22) 175 (79) 152 (69)<br />
8 (2.44) 280 (127) 230 (104)<br />
101228756 RDX SH/LD 11 (3.35) 359 (163) 288 (131)<br />
100156995 HMX SH 16 (4.88) 490 (222) 385 (175)<br />
101233690 HMX SH/LD 22 (6.71) 648 (294) 502 (228)<br />
101307494 RDX Mirage ®<br />
100005311 RDX SH 14<br />
25.7°/<br />
128.5°<br />
Premium Vann<br />
17,000<br />
(1172)<br />
427,000<br />
(193 651)<br />
14 spf SH<br />
101228756 RDX SH/LD 4 (1.22) 177 (80) 152 (69)<br />
100156995 HMX SH 8 (2.44) 286 (130) 230 (104)<br />
101233690 HMX SH/LD 11 (3.35) 368 (167) 288 (131)<br />
16 (4.88) 504 (228) 386 (175)<br />
22 (6.71) 667 (302) 503 (228)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
5-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
101268719 RDX SH 18 60°/120° Premium Vann<br />
101292616 RDX BH 21 60°/120° Premium Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
17,000<br />
(1172)<br />
427,000<br />
(193 651)<br />
18 spf SH<br />
3/Plane 4 (1.22) 181 (82) 152 (69)<br />
16,000<br />
(1103)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
427,000<br />
(193 651)<br />
Weights<br />
8 (2.44) 296 (134) 229 (104)<br />
11 (3.35) 383 (174) 288 (130)<br />
16 (4.88) 527 (239) 385 (174)<br />
22 (6.71) 701 (318) 501 (227)<br />
21 spf BH<br />
3/Plane 4 (1.22) 185 (84) 152 (69)<br />
8 (2.44) 304 (138) 229 (104)<br />
11 (3.35) 393 (178) 287 (130)<br />
16 (4.88) 540 (245) 384 (174)<br />
22 (6.71) 717 (325) 500 (227)<br />
5-30 <strong>Perforating</strong> Solutions<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
Spacer<br />
lb (kg)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
5 1/8-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
101240223 RDX SH 6 135° Premium Vann<br />
100005319 RDX BH 12 OMNI Premium Vann<br />
100005326 RDX BH/LD OMNI Premium<br />
Industry<br />
St<strong>and</strong>ard<br />
Pressure<br />
Rating<br />
psi (bar)<br />
18,000<br />
(1241)<br />
16,000<br />
(1103)<br />
16,000<br />
(1103)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
520,000<br />
(235 868)<br />
520,000<br />
(239 929)<br />
520,000<br />
(239 929)<br />
Weights<br />
<strong>Perforating</strong> Solutions 5-31<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
6 spf SH<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 185 (84) 152 (69)<br />
8 (2.44) 304 (138) 229 (104)<br />
11 (3.35) 393 (178) 287 (130)<br />
16 (4.88) 540 (245) 384 (174)<br />
22 (6.71) 717 (325) 500 (227)<br />
12 spf 22.7 g<br />
4 (1.22) 181 (82) 157 (71)<br />
100157006 HMX BH 8 (2.44) 290 (132) 239 (108)<br />
120038060 HMX BH/LD 11 (3.35) 372 (169) 300 (136)<br />
100005324 RDX DP 16 (4.88) 505 (229) 401 (182)<br />
100005325 RDX DP/LD 22 (6.71) 672 (305) 523 (237)<br />
100014352 HMX DP 12 spf 28 g SH<br />
100005340 HMX DP/LD 4 (1.22) 180 (81) 157 (71)<br />
101210674 HMX Millennium 8 (2.44) 287 (130) 239 (108)<br />
101343830 HNS DP 11 (3.35) 368 (167) 300 (136)<br />
100005311 RDX SH 16 (4.88) 499 (226) 401 (182)<br />
101228756 RDX SH/LD 22 (6.71) 663 (301) 523 (237)<br />
100156995 HMX SH<br />
101233690 HMX SH/LD<br />
101307494 RDX Mirage ®
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
100157007 RDX SH 14<br />
5 1/8-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
25.7°/<br />
128.5°<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
Premium Vann<br />
16,000<br />
(1103)<br />
520,000<br />
(239 929)<br />
14 spf 28 g SH<br />
100157011 HMX SH 4 (1.22) 182 (82) 157 (71)<br />
101292616 RDX BH 21 60°/120° Premium Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
16,000<br />
(1103)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
520,000<br />
(239 929)<br />
8 (2.44) 292 (133) 238 (108)<br />
11 (3.35) 375 (170) 298 (135)<br />
16 (4.88) 511 (232) 399 (181)<br />
22 (6.71) 679 (308) 520 (236)<br />
14 spf 32 g SH<br />
4 (1.22) 186 (84) 157 (71)<br />
8 (2.44) 302 (137) 238 (108)<br />
11 (3.35) 389 (176) 298 (135)<br />
16 (4.88) 531 (241) 399 (181)<br />
22 (6.71) 708 (321) 520 (236)<br />
5-32 <strong>Perforating</strong> Solutions<br />
Length<br />
ft (m)<br />
Weights<br />
Loaded<br />
lb (kg)<br />
21 spf<br />
Spacer<br />
lb (kg)<br />
3/Plane 4 (1.22) 190 (86) 156 (71)<br />
8 (2.44) 311 (141) 236 (107)<br />
11 (3.35) 402 (182) 296 (134)<br />
16 (4.88) 553 (251) 395 (179)<br />
22 (6.71) 734 (333) 515 (234)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
100157007 RDX SH 14<br />
101307494 RDX Mirage ®<br />
5 3/4-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
25.7°/<br />
128.5°<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
Premium Vann<br />
10 45°/135° Premium Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
17,000<br />
(1172)<br />
17,000<br />
(1172)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
512,000<br />
(232 200)<br />
512,000<br />
(232 200)<br />
Weights<br />
<strong>Perforating</strong> Solutions 5-33<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
14 spf SH<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 216 (98) 192 (87)<br />
101357518 RDX Maxim 8 (2.44) 344 (156) 293 (133)<br />
101292616 RDX BH 21 60°/120° Premium Vann<br />
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
100156993 RDX DP 12<br />
16,000<br />
(1103)<br />
6-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
51.4°/<br />
154.2°<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
Premium Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
15,000<br />
(1034)<br />
512,000<br />
(232 200)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
672,000<br />
(304 762)<br />
11 (3.35) 442 (200) 369 (167)<br />
16 (4.88) 647 (294) 496 (225)<br />
22 (6.71) 859 (389) 648 (294)<br />
21 spf SH<br />
4 (1.22) 216 (98) 192 (87)<br />
8 (2.44) 344 (156) 293 (133)<br />
11 (3.35) 442 (200) 369 (167)<br />
16 (4.88) 647 (294) 496 (225)<br />
22 (6.71) 859 (389) 648 (294)<br />
Length<br />
ft (m)<br />
Weights<br />
Loaded<br />
lb (kg)<br />
12 spf DP<br />
Spacer<br />
lb (kg)<br />
100156994 HMX DP 4 (1.22) 272 (123) 216 (98)<br />
100156992 HMX BH 8 (2.44) 447 (203) 318 (144)<br />
100156991 RDX BH 15 (4.57) 706 (320) 497 (225)<br />
12 spf BH<br />
4 (1.22) 251 (114) 216 (98)<br />
8 (2.44) 398 (181) 318 (144)<br />
15 (4.57) 608 (276) 497 (225)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
6 1/2-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
101228037 RDX Mirage ® 12 45°/135° Premium Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
15,000<br />
(1034)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
480,000<br />
(217 687)<br />
Weights<br />
5-34 <strong>Perforating</strong> Solutions<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
12 spf BH Mirage<br />
Spacer<br />
lb (kg)<br />
101304878 RDX Mirage 4 (1.22) 275 (125) 240 (109)<br />
101213474 RDX SH 8 (2.44) 431 (195) 354 (160)<br />
101212693 RDX SH/LD 16 (4.88) 733 (333) 582 (264)<br />
101357518 RDX Maxim 12 spf SH/LD<br />
101228037 RDX Mirage 14 138° Premium Vann<br />
15,000<br />
(1034)<br />
480,000<br />
(217 687)<br />
4 (1.22) 277 (126) 240 (109)<br />
8 (2.44) 435 (197) 354 (160)<br />
16 (4.88) 743 (337) 582 (264)<br />
14 spf SH Mirage<br />
101304878 RDX Mirage SH 4 (1.22) 277 (124) 240 (109)<br />
101213474 RDX SH 8 (2.44) 437 (198) 354 (160)<br />
101357518 RDX Maxim 16 (4.88) 754 (342) 582 (264)<br />
14 spf SH<br />
4 (1.22) 283 (128) 240 (109)<br />
8 (2.44) 451 (205) 354 (160)<br />
16 (4.88) 784 (355) 582 (264)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
6 1/2-in. High-Pressure Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
101228037 RDX Mirage ® 12 45°/135° Premium Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
20,000<br />
(1379)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
719,000<br />
(326 132)<br />
Weights<br />
<strong>Perforating</strong> Solutions 5-35<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
12 spf BH Mirage<br />
Spacer<br />
lb (kg)<br />
101304878 RDX Mirage SH 4 (1.22) 298 (135) 268 (121)<br />
101213474 RDX SH 8 (2.44) 476 (216) 410 (186)<br />
101212693 RDX SH/LD 16 (4.88) 824 (370) 684 (310)<br />
101357518 RDX Maxim 12 spf SH/LD<br />
101228037 RDX Mirage 14 138° Premium Vann<br />
20,000<br />
(1379)<br />
480,000<br />
(217 687)<br />
4 (1.22) 300 (136) 268 (121)<br />
8 (2.44) 481 (218) 410 (186)<br />
16 (4.88) 834 (378) 684 (310)<br />
14 spf SH Mirage<br />
101304878 RDX Mirage SH 4 (1.22) 300 (136) 268 (121)<br />
101213474 RDX SH 8 (2.44) 482 (219) 410 (186)<br />
101357518 RDX Maxim 16 (4.88) 841 (382) 684 (310)<br />
14 spf SH<br />
4 (1.22) 305 (138) 268 (121)<br />
8 (2.44) 496 (225) 410 (186)<br />
16 (4.88) 871 (395) 684 (310)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
7-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
100005325 RDX DP/LD 12 45°/135° Premium Vann<br />
100005340 HMX DP/LD 45°/135° Premium<br />
Industry<br />
St<strong>and</strong>ard<br />
Pressure<br />
Rating<br />
psi (bar)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
Weights<br />
5-36 <strong>Perforating</strong> Solutions<br />
13,000<br />
(897)<br />
13,000<br />
(897)<br />
802,000<br />
(363 719)<br />
802,000<br />
(363 719)<br />
Length<br />
ft (m)<br />
Loaded<br />
lb (kg)<br />
12 spf BH Mirage<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 326 (148) 292 (132)<br />
101228037 RDX Mirage ® 8 (2.44) 494 (224) 421 (191)<br />
101304878 RDX Mirage 16 (4.88) 831 (377) 679 (308)<br />
101213474 RDX SH 12 spf SH/LD<br />
101212693 RDX SH/LD 4 (1.22) 328 (149) 292 (132)<br />
101207997 HMX Millennium 8 (2.44) 499 (226) 421 (191)<br />
101357518 RDX Maxim 16 (4.88) 841 (381) 679 (308)<br />
101228037 RDX Mirage 14 138° Premium Vann<br />
13,000<br />
(897)<br />
802,000<br />
(363 719)<br />
12 spf Millennium<br />
4 (1.22) 356 (161) 292 (132)<br />
8 (2.44) 565 (256) 421 (191)<br />
16 (4.88) 984 (446) 679 (308)<br />
14 spf SH Mirage<br />
101304878 RDX Mirage SH 4 (1.22) 328 (149) 291 (132)<br />
101213474 RDX SH 8 (2.44) 501 (227) 420 (190)<br />
101357518 RDX Maxim 16 (4.88) 847 (384) 677 (307)<br />
14 spf SH<br />
4 (1.22) 334 (151) 291 (132)<br />
8 (2.44) 515 (234) 420 (190)<br />
16 (4.88) 877 (398) 677 (307)
Charge<br />
Part No.<br />
Explosive<br />
Type<br />
Charge<br />
Type<br />
7-in. Premium VannGun ® Assemblies<br />
SPF Phasing<br />
Gun<br />
Material<br />
Type<br />
Gun Thread<br />
101414821 HMX Mirage ® 18 60°/120° Premium Vann<br />
101414821 HMX Mirage 18 60°/120° Premium Vann<br />
Pressure<br />
Rating<br />
psi (bar)<br />
<strong>Perforating</strong> Solutions 5-37<br />
13,000<br />
(897)<br />
20,000<br />
(1379)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
802,000<br />
(363 719)<br />
802,000<br />
(363 719)<br />
Length<br />
ft (m)<br />
Weights<br />
Loaded<br />
lb (kg)<br />
18 spf SH Mirage<br />
4 (1.22) 334 (151) 291 (132)<br />
8 (2.44) 515 (234) 420 (190)<br />
16 (4.88) 877 (398) 677 (307)<br />
18 spf SH Mirage XHP<br />
Spacer<br />
lb (kg)<br />
4 (1.22) 334 (151) 291 (132)<br />
8 (2.44) 515 (234) 420 (190)<br />
16 (4.88) 877 (398) 677 (307)
Gun Size<br />
in.<br />
1.563<br />
2<br />
2.5<br />
2.75<br />
Gun Washover/Fishing Specifications<br />
Gun OD<br />
in.*<br />
(Gun OD after<br />
shooting)<br />
Maximum Shot<br />
(Density) per foot<br />
SPF<br />
1.745 4<br />
1.76 6<br />
2.166 4<br />
2.203 6<br />
TBD* 4<br />
2.67 6<br />
2.97 4<br />
2.79 5<br />
3.09 6<br />
Minimum Casing<br />
Size<br />
(for washing over<br />
w/o<br />
milling guns)<br />
5-38 <strong>Perforating</strong> Solutions<br />
4 in.<br />
4 in.<br />
4.5 in. 13.5 #/ft<br />
4.5 in. 9.5 #/ft<br />
3.125 3.25 9 5 in. 15 #/ft<br />
3.375<br />
3.68 4<br />
3.68 6<br />
3.53 12<br />
5.5 in. 23 #/ft<br />
4 4.26 6 6 5/8 in. 35 #/ft<br />
4.625<br />
5<br />
5.125<br />
4.87 5<br />
4.88 6<br />
4.86 8<br />
4.87 11<br />
4.96 12<br />
4.79 14<br />
5.2 12<br />
5.3 14<br />
5.23 18<br />
5.41 6<br />
5.21 12<br />
5.38 14<br />
5.36 21<br />
7 in. 35 #/ft<br />
7 in. 26 #/ft/**<br />
7 5/8 in. 39 #/ft<br />
6 6.79 12 9 5/8 in.<br />
6.5 6.76 14 9 5/8 in. 71.8 #/ft<br />
7<br />
7.14 12<br />
7.15 14<br />
9 5/8 in. 58.4 #/ft<br />
*Worst Case-Atmospheric pressure, submerged in water.<br />
**It is possible to washover 5 in. guns in 7 in. 29-lb casing, but washover pipe to be used is<br />
not a common size <strong>and</strong> is difficult to find.
OD SPF<br />
1 9/16 6<br />
2<br />
Gun Swell Information<br />
Gun Charge Test Results<br />
Shot Phase<br />
deg<br />
Charge<br />
Part No.<br />
Type<br />
Explosive Weight<br />
gm<br />
Tested In<br />
Air/Water<br />
Maximum Swell<br />
in.<br />
60 100157028<br />
1.760<br />
Millennium 3.4 water<br />
0 100157028 1.705<br />
4 0 100008017<br />
air 2.246<br />
SDP<br />
60 100008017<br />
2.221<br />
6.8<br />
0 101208224<br />
water<br />
2.177<br />
6<br />
Millennium<br />
101208224 2.225<br />
60<br />
101603801* MaxForce ® 7 air 2.193<br />
2.38 6 60 101590845 MaxForce 10 water 2.529<br />
2 1/2 6 60<br />
101206251 DP 11 water 2.680<br />
101418095* Millennium II 11.1 air 2.705<br />
4<br />
5<br />
22 LS<br />
180<br />
100158220<br />
100158220<br />
100157026<br />
DP LD<br />
SDP<br />
13<br />
13<br />
14.7<br />
water<br />
2.781<br />
2.810<br />
2.971<br />
2 3/4<br />
6<br />
60<br />
100005329<br />
100005329<br />
100158220<br />
101206793<br />
DP<br />
DP LD<br />
BH<br />
12.5<br />
12.5<br />
13<br />
14.7<br />
air<br />
2.853<br />
2.898<br />
2.893<br />
2.850<br />
100010399 SDP 14.7 water<br />
2.954<br />
60 LS<br />
101233817<br />
101233817<br />
Millennium<br />
15<br />
15<br />
2.892<br />
2.915<br />
2 7/8 6 60 101233817 Millennium 15 water 3.047<br />
2 7/8 HW 6 60 101233817 Millennium 15 air 3.044<br />
2.88 6 60 101388407 Millennium HNS 18.5 water 3.060<br />
3 1/8 6 60 101388406 Millennium 17.5 HMX 3.333<br />
3.38 5 60 101320075 Dominator ® 25 water 3.497<br />
G-Force<br />
3 3/8<br />
®<br />
180 101233817 Millennium 15 water 3.42<br />
4<br />
60<br />
90<br />
100005322<br />
100005327<br />
100005327<br />
DP<br />
32<br />
32<br />
32<br />
air<br />
water<br />
3.676<br />
3.592<br />
3.555<br />
180 100008249 SDP 25 3.546<br />
100005333 DP 22 air 3.610<br />
6<br />
60<br />
60 LS<br />
100008249<br />
101207640<br />
100008249<br />
SDP<br />
SDP LD<br />
SDP<br />
25<br />
24<br />
25<br />
3.600<br />
3.615<br />
3.600<br />
60<br />
101233819<br />
101309223<br />
Millennium<br />
Dominator<br />
25<br />
25<br />
water<br />
3.645<br />
3.695<br />
8 180 100008251<br />
14 3.458<br />
12<br />
12<br />
30/150<br />
100008251<br />
100005312<br />
BH<br />
14<br />
14<br />
3.520<br />
3.568<br />
3 1/2 6 60 101309223 Dominator 25 air 3.845<br />
4<br />
4<br />
7<br />
90<br />
150<br />
101210636<br />
101228756<br />
Millennium<br />
SH LD<br />
39<br />
28<br />
water<br />
water<br />
4.260<br />
4.280<br />
<strong>Perforating</strong> Solutions 5-39
OD SPF<br />
4.25 8 150 101228756 SH LD 28 water 4.487<br />
4 5/8<br />
5<br />
G-Force ®<br />
180 100005327 DP 32 water 4.696<br />
4 10/350 101466192 KleenZone 39 water 4.705<br />
5<br />
6 60<br />
8 180<br />
60 101210636 Millennium 39 air 4.944<br />
45/135 101321963 SH 56.5 water 4.904<br />
100005327<br />
32 air 4.876<br />
DP<br />
100005327 32 water 4.806<br />
100005326<br />
23 air 4.860<br />
DP LD<br />
100005326 23<br />
4.780<br />
100005311 SH 28 4.770<br />
11 140/160 100005324<br />
22.7 4.868<br />
DP<br />
100014352 23 4.834<br />
12 30/150<br />
Gun Swell Information<br />
Gun Charge Test Results<br />
Shot Phase<br />
deg<br />
Charge<br />
Part No.<br />
Type<br />
100005340 DP LD 22.7 4.925<br />
water<br />
100005326 BH LD 22.7 4.840<br />
100005311 SH<br />
Explosive Weight<br />
gm<br />
101228756 SH LD 28<br />
4.895<br />
5-40 <strong>Perforating</strong> Solutions<br />
4.813<br />
14 25.7/128.5 100005311 SH 4.790<br />
18 45/135 100156990 BH 20 4.730<br />
8 135 101350449 Maxim 47 water 5.202<br />
12 30/150 100005311<br />
5.196<br />
SH<br />
100005311 5.207<br />
14 25.7/128.5<br />
28<br />
101228756 SH LD water<br />
5.304<br />
18<br />
101269719 SH 5.229<br />
60/120<br />
21 101292616 BH 21 5.198<br />
6 45/135 101240223 SH 56.5<br />
Tested In<br />
Air/Water<br />
Maximum Swell<br />
in.<br />
5 1/8<br />
12<br />
14<br />
30/150<br />
25.7/128.5<br />
100005326<br />
100157007<br />
BH LD<br />
SH<br />
22.7<br />
32<br />
water<br />
5.210<br />
5.332<br />
21 60/120 101292616 BH 20 5.268<br />
5 3/4<br />
14<br />
21<br />
25.7/128.5<br />
3/plane 60<br />
101272769<br />
101292616<br />
SH LD<br />
BH<br />
34<br />
21<br />
water<br />
water<br />
5.945<br />
6.065<br />
6 1/2<br />
14 138 101304878 Mirage ® BH 47<br />
water<br />
6.685<br />
12 45/135 101212693 SH LD 56.5 6.715<br />
6 1/2 HP 12 45/135 101212693 SH LD 56.5 water 6.762<br />
7<br />
12<br />
14<br />
45/135<br />
138<br />
101210063<br />
101213474<br />
SH LD<br />
SH<br />
56.5 water<br />
7.125<br />
7.143<br />
18 3/plane 60 101498239 BH LD 45 water 7.130<br />
*Special gun length requirements<br />
The above chart was taken from actual tests conducted by <strong>Halliburton</strong> Technology on RDX <strong>and</strong> HMX charges. It can be used as a<br />
general guideline for all explosives. If you have questions regarding these systems, or systems that are not listed, please contact your<br />
local <strong>Halliburton</strong> representative.<br />
All tests were conducted at ambient temperature <strong>and</strong> pressure.<br />
5.413
Capsule Gun Systems<br />
Dyna-Star ® Capsule Gun<br />
Jet Research Center’s Dyna-Star® capsule gun is an<br />
economical, second-generation capsule perforating system.<br />
This system is partially expendable <strong>and</strong> uses a stainless steel<br />
strip in its through-tubing technology.<br />
Applications<br />
2.125-in. <strong>and</strong> 1.6875-in. gun systems at 4-spf <strong>and</strong> 6-spf<br />
1.6875-in. system rated at 14,000 psi <strong>and</strong> up to 370°F<br />
(HMX version) in dry gas or fluid<br />
2.125-in. system rated at 15,000 psi <strong>and</strong> up to 370°F<br />
(HMX version) in dry gas or fluid<br />
Rated up to 370°F (HMX version) in dry gas or fluid—<br />
may be used in hostile environments only if special<br />
precautions are taken. Contact JRC for more<br />
information<br />
Features<br />
Deep penetrating charges<br />
Uses same charges as the Dyna-Cap® four-wire strip gun<br />
to minimize inventory<br />
Available in 0° phasing<br />
Rollover sleeves to keep the gun in its optimum<br />
orientation<br />
Can cut guns to required length in the field<br />
Economical operation<br />
Can use 18-ft long strips without t<strong>and</strong>em<br />
Ease of gun retrieval after shooting<br />
Dyna-Star® Capsule Gun<br />
<strong>Perforating</strong> Solutions 5-41<br />
HAL11757
Deep Star Capsule Gun<br />
Jet Research Center's Deep Star perforating system is a<br />
third-generation, state-of-the-art, through-tubing capsule<br />
perforating system with improved charge performance <strong>and</strong><br />
running characteristics.<br />
Applications<br />
2.125-in. <strong>and</strong> 1.6875-in. OD gun systems<br />
Rated at 15,000 psi <strong>and</strong> 350°F in dry gas, fluid, or hostile<br />
environments<br />
Higher ratings available upon request<br />
Designed for deep, high temperature, high pressure wells<br />
Features<br />
Extremely deep penetrating charges<br />
Higher shot densities without charge interference (up to<br />
8-spf with the 1.6875-in. system-patent pending)<br />
attained using hydrodynamic modeling techniques<br />
Most available in seven phasings: 0°, 90° downside, 90°<br />
spiral, triphase (patented), pentaphase, heptaphase, <strong>and</strong><br />
octaphase<br />
Compatible interval coverage with the innovative “gullwing”<br />
t<strong>and</strong>em (patented), which minimizes strip<br />
deformation, allowing easier retrieval<br />
Hardware offset in conjunction with charge center<br />
gravity to optimize gun stability <strong>and</strong> orientation<br />
Corrosion-resistant steel alloy charge cases <strong>and</strong> carrier<br />
strips permit the use of the Deep Star system in hostile<br />
environments<br />
No gaps in shot pattern at joints in strips<br />
Ease of gun removal after shooting<br />
2.125-in. 90° Spiral Phase Deep Star Capsule Gun<br />
5-42 <strong>Perforating</strong> Solutions<br />
HAL11758
1.6875-in. <strong>and</strong> 2.125-in. Deep Star Debris Fill Data<br />
Inches of Fill Per Charge<br />
1.2<br />
1.0<br />
0.8<br />
0.6<br />
0.4<br />
0.2<br />
HAL11759<br />
0<br />
2.125-in.<br />
1.6875-in.<br />
1 2 3 4 5 6 7 8 9 10<br />
Pipe ID (inches)<br />
Pipe OD<br />
in.<br />
Deep Star Fill Data (Shot in Water)<br />
Pipe Weight<br />
lb/ft<br />
Pipe ID<br />
in.<br />
2 3/8 4.7 1.995<br />
2 7/8 6.5 2.441<br />
3 1/2 9.3 2.992<br />
4 11.0 3.476<br />
4 1/2 11.6 4.000<br />
5 15.0 4.408<br />
5 1/2 17.0 4.892<br />
7 32.0 6.094<br />
7 5/8 33.7 6.765<br />
9 5/8 47.0 8.681<br />
Notes:<br />
1. Fill data is approximate.<br />
2. When shot in gas, the debris is smaller <strong>and</strong> will occupy less volume.<br />
Fill per 1 11/16-in.<br />
Charge<br />
in. (mm)<br />
Fill per 2 1/8-in.<br />
Charge<br />
in. (mm)<br />
<strong>Perforating</strong> Solutions 5-43<br />
0.322<br />
(8.17)<br />
0.215<br />
(5.45)<br />
0.143<br />
(3.63)<br />
0.106<br />
(2.69)<br />
0.080<br />
(2.03)<br />
0.066<br />
(1.67)<br />
0.053<br />
(1.36)<br />
0.034<br />
(0.88)<br />
0.028<br />
(0.71)<br />
0.017<br />
(0.43)<br />
0.920<br />
(23.37)<br />
0.615<br />
(15.61)<br />
0.409<br />
(10.39)<br />
0.303<br />
(7.70)<br />
0.229<br />
(5.81)<br />
0.188<br />
(4.79)<br />
0.153<br />
(3.89)<br />
0.099<br />
(2.50)<br />
0.080<br />
(2.03)<br />
0.049<br />
(1.23)<br />
11
Ported Gun <strong>Perforating</strong> System<br />
Jet Research Center’s ported gun perforating systems provide<br />
users with economical, reusable guns for multi-purpose<br />
applications.<br />
Applications<br />
Multi-zone shooting on a single run with select fire subs<br />
Hostile environment<br />
Short guns available for squeeze applications<br />
Features<br />
Charges are protected from well fluids, formation<br />
pressure, <strong>and</strong> abrasion<br />
Debris retained in hollow carrier<br />
Carrier protects casing from detonation shock<br />
Charges for high-temperature environments are<br />
available upon request<br />
Charges are tested to API st<strong>and</strong>ards<br />
Charges are designed to minimize internal damage to the<br />
gun body, prolonging life<br />
The gun design has minimized charge interference<br />
Options<br />
3.125-in. to 5-in. gun sizes<br />
Big-hole <strong>and</strong> deep penetrating charges<br />
90° <strong>and</strong> 120° phasing (other phase angles available upon<br />
request)<br />
3.125-in. Ported Gun<br />
5-44 <strong>Perforating</strong> Solutions<br />
HAL11760
Firing Heads<br />
Detonation Interruption Device<br />
The detonation interruption device (DID) provides added<br />
safety for the VannSystem® service by helping to prevent<br />
firing at surface conditions. This device contains a eutectic<br />
metal that has a very low melting point. When the metal is<br />
in a solid state, the firing head could detonate, but the<br />
explosive train will not transmit through the interrupt<br />
device to the guns.<br />
Features<br />
Compatible with other firing heads<br />
Disables transmission of explosive train at the surface<br />
Used with redundant firing heads<br />
Operation<br />
The eutectic metal will remain solid as the assembly lowers<br />
into the hole (assuming the tool temperature is below 117°F).<br />
When exposed to the bottomhole temperature (minimum<br />
135°F for operational purposes), the metal becomes liquid,<br />
allowing the transfer of the explosive train from the firing<br />
head to the gun.<br />
To help prevent accidental gun detonation when lowering or<br />
retrieving unfired guns, the metal returns to a solid state<br />
upon reaching a cooler surface temperature.<br />
Note: The eutectic material utilized actually melts at 117°F.<br />
At 117°F or above, the DID assembly will not prevent<br />
detonation. For safe operation, it should be assumed that<br />
detonation transfer will occur if the tool is at or above 110°F.<br />
SAP No.<br />
100155745<br />
101204860<br />
100155746<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 (50.8) 6<br />
Acme 2G<br />
2 3/8 (60.33) 6P<br />
Acme Box × Pin<br />
2 7/8 (73.03) 6P<br />
Acme Box × Pin<br />
Detonation Interruption Device<br />
Detonation Interruption Device (DID) Specifications<br />
Maximum OD<br />
in. (mm)<br />
2.50<br />
(63.5)<br />
2.75<br />
(69.85)<br />
3.375<br />
(85.73)<br />
Makeup Length<br />
ft (m)<br />
1.58<br />
(0.48)<br />
3.70<br />
(1.13)<br />
3.04<br />
(0.93)<br />
<strong>Perforating</strong> Solutions 5-45<br />
HAL10519<br />
Maximum Operating<br />
Pressure<br />
psi (bar)<br />
N/A<br />
20,000<br />
(1380)<br />
25,000<br />
(1725)<br />
Maximum temperature is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Minimum Required<br />
Temperature Rating<br />
°F (°C)<br />
135<br />
(57)<br />
135<br />
(57)<br />
135<br />
(57)<br />
Tensile Strength<br />
lb (kg)<br />
121,000<br />
(54 885)<br />
140,000<br />
(63 400)<br />
246,000<br />
(111 500)
Mechanical Firing Head<br />
The extended mechanical firing head (MFH) is a special<br />
application tool. It should be used only when well conditions<br />
preclude the use of an alternate firing device. Whenever it is<br />
used on a job, the MFH must be used according to<br />
<strong>Halliburton</strong> st<strong>and</strong>ard operating procedures.<br />
Operation<br />
The operation of the MFH depends on the amount of force<br />
delivered to the firing pin by the detonating bar. This firing<br />
pin must be hit with enough force to shear the spiral pin,<br />
which holds the firing pin in place, <strong>and</strong> to detonate the<br />
initiator. The firing pin is driven into a percussion detonator,<br />
which fires the guns.<br />
The detonation interruption device (DID) <strong>and</strong> a minimum<br />
of 10 ft of safety spacer must always be used with the MFH.<br />
SAP No.<br />
100155741<br />
100005223<br />
100005228<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
1 7/16 (36.51) 8 UN 2 B Box ×<br />
1.90 (48.26) NU 10 Rd Pin<br />
1.90 (48.26) NU 10 Rd Pin ×<br />
2 3/8 (60.33) 6P Acme Box<br />
2 3/8 (60.33) EUE 8 Rd Pin ×<br />
2 7/8 (73.03) 6P Acme Box<br />
Mechanical Firing Head (MFH) Specifications<br />
Maximum OD<br />
in. (mm)<br />
2.0<br />
(50.8)<br />
2.75<br />
(69.85)<br />
3.375<br />
(85.73)<br />
5-46 <strong>Perforating</strong> Solutions<br />
HAL15358<br />
Makeup Length<br />
(w/Tubing Sub)<br />
ft (m)<br />
1.48<br />
(.45)<br />
4.92<br />
(1.50)<br />
4.92<br />
(1.50)<br />
Mechanical Firing<br />
Head (MFH)<br />
Burst <strong>and</strong> collapse pressures are determined by h<strong>and</strong>ling sub.<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Maximum Operating<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
HAL15376<br />
Firing Head<br />
Sub-Assembly<br />
Minimum ID<br />
(No-Go)<br />
in. (mm)<br />
1.53<br />
(38.86)<br />
1.56<br />
(39.62)<br />
1.56<br />
(39.62)<br />
Tensile Strength<br />
(FH Body)<br />
lb (kg)<br />
60,000<br />
(27 200)<br />
140,000<br />
(63 400)<br />
238,000<br />
(107 900)
Model II-D Mechanical Firing Head<br />
The model II-D mechanical firing head is a pressure-assisted<br />
mechanical firing head. The detonating bar strikes the firing<br />
pin, releasing the firing piston. Hydrostatic pressure then<br />
forces the firing piston into the initiator.<br />
Features<br />
Cannot be detonated accidentally at surface<br />
Ideal for use in mud environments where spudding may be<br />
necessary<br />
Used in deviated wells<br />
Operation<br />
The model II-D firing head requires a minimum of 1,500 psi<br />
hydrostatic pressure in the tubing to actuate the firing head<br />
properly.<br />
Adding more pressure to the tubing after the detonating bar<br />
has struck the firing pin will not actuate the firing head.<br />
SAP No.<br />
100014156<br />
100005227<br />
Thread Size <strong>and</strong> Type<br />
in. (mm)<br />
1.90 (48.26) EUE 10 Rd<br />
Pin × 2 3/8 (60.33)<br />
6P Acme Box<br />
2 3/8 (60.33) EUE 8 Rd Pin<br />
× 2 7/8 (73.03) 6P Acme<br />
<strong>Perforating</strong> Solutions 5-47<br />
HAL15377<br />
Model II-D Mechanical<br />
Firing Head<br />
Model II-D Mechanical Firing Head Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
2.75<br />
(69.85)<br />
3.375<br />
(85.73)<br />
Minimum ID<br />
(No-Go)<br />
in. (mm)<br />
1.56<br />
(39.62)<br />
1.56<br />
(39.62)<br />
Makeup Length<br />
(w/tubing sub)<br />
ft (m)<br />
4.92<br />
(1.50)<br />
4.92<br />
(1.50)<br />
Burst <strong>and</strong> collapse pressures are determined by h<strong>and</strong>ling sub.<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
HAL15378<br />
Model II-D Mechanical<br />
Firing Head Assembly<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
1,500<br />
(103)<br />
1,500<br />
(103)<br />
Tensile<br />
Strength<br />
(FH body)<br />
lb (kg)<br />
140,000<br />
(63 400)<br />
238,000<br />
(107 900)
Model III-D Mechanical Firing Head<br />
The model III-D mechanical firing head is a pressure-assisted<br />
mechanical firing head. The detonating bar strikes the firing<br />
pin, releasing the firing piston. Hydrostatic pressure then<br />
forces the firing piston into the initiator.<br />
The model III-D firing head requires a minimal amount of<br />
hydrostatic pressure to actuate the firing head.<br />
Features<br />
Cannot be detonated accidentally at surface<br />
Requires minimal hydrostatic pressure to actuate the firing<br />
head<br />
Operation<br />
The model III-D firing head requires a minimum of 250 psi<br />
hydrostatic pressure in the tubing to actuate the firing head<br />
properly. This minimal actuating pressure is ideal for<br />
applications that require maximum differential pressures.<br />
If a detonating bar is dropped on the model III-D firing head<br />
with less than 250 psi hydrostatic pressure in the tubing, <strong>and</strong><br />
the head does not fire, increasing the hydrostatic pressure in<br />
the tubing may cause it to fire.<br />
SAP No.<br />
100155742<br />
100005191<br />
Thread Size <strong>and</strong> Type<br />
in. (mm)<br />
1.90 (48.26) EUE 10 Rd Pin ×<br />
2 3/8 (60.33) 6P Acme Box<br />
2 3/8 (60.33) EUE 8 Rd Pin ×<br />
2 7/8 (73.03) 6P Acme Box<br />
5-48 <strong>Perforating</strong> Solutions<br />
HAL15379<br />
Model III-D Mechanical<br />
Firing Head<br />
Model III-D Mechanical Firing Head Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
2.75<br />
(69.85)<br />
3.375<br />
(85.73)<br />
Minimum ID<br />
(No-Go)<br />
in. (mm)<br />
1.56<br />
(39.62)<br />
1.56<br />
(39.62)<br />
Makeup<br />
Length<br />
(w/Tubing Sub)<br />
ft (m)<br />
4.92<br />
(1.50)<br />
4.92<br />
(1.50)<br />
Burst <strong>and</strong> collapse pressures are determined by h<strong>and</strong>ling sub.<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
8,000<br />
(550)<br />
8,000<br />
(550)<br />
HAL15380<br />
Model III-D Mechanical<br />
Firing Head Assembly<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
250<br />
(17)<br />
250<br />
(17)<br />
Tensile Strength<br />
(FH Body)<br />
lb (kg)<br />
140,000<br />
(63 400)<br />
238,000<br />
(107 900)
Pressure-Actuated Firing Head<br />
The 1 11/16-in. pressure-actuated firing head (PAF) can run<br />
with small-OD tubing or coiled tubing to detonate small-OD<br />
perforating guns. The PAF is detonated by applied pressure.<br />
Features<br />
Can be run on the top <strong>and</strong> bottom of the gun assembly<br />
Initiates a bridge-plug setting tool<br />
Initiates tubing cutters<br />
Detonates tubing punch charges for squeeze or<br />
circulating jobs<br />
Can be run to remain closed after detonation<br />
Can be modified to be run as a slickline-retrievable firing<br />
head <strong>and</strong> a time-delay firing head (TDF)<br />
Operation<br />
The 1 11/16-in. PAF consists of an upper housing with<br />
circulating ports, a firing piston that is shear-pinned in place<br />
across the circulating ports, <strong>and</strong> an initiator contained in a<br />
lower housing.<br />
Pressure applied to the tubing string shears the shear set,<br />
which forces the firing piston into the initiator to detonate<br />
the explosive component attached to the PAF. The downward<br />
movement of the firing piston opens the circulating ports.<br />
SAP No.<br />
100005224<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
1.315 (33.40) NU-10 Rd<br />
Pin × 17/16 (36.51)<br />
8 UN-2 B Box<br />
Pressure-Actuated<br />
Firing Head (PAF)<br />
Pressure-Actuated Firing Head (PAF) Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
1.688<br />
(42.88)<br />
No. <strong>and</strong> ID<br />
of Ports<br />
in. (mm)<br />
2 @ 0.75<br />
(19.05)<br />
Flow Area<br />
of Ports<br />
in. 2 (cm 2 )<br />
0.88<br />
(5.68)<br />
Makeup<br />
Length<br />
ft (m)<br />
<strong>Perforating</strong> Solutions 5-49<br />
0.73<br />
(0.22)<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
HAL10561<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
17,000<br />
(1170)<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
2,200<br />
(150)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
65,000<br />
(29 400)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
27,000<br />
(1860)
Model K <strong>and</strong> K-II Firing Heads<br />
The model K <strong>and</strong> K-II firing heads were<br />
developed for conditions that are<br />
unfavorable for dropping a detonating<br />
bar in a horizontal well. The model K<br />
<strong>and</strong> K-II firing heads are pressuresensitive<br />
tools designed to hydraulically<br />
detonate at a prescribed pressure. These<br />
firing heads use tubing pressure applied<br />
to a piston-type firing pin.<br />
Features<br />
Allows the operator to determine the<br />
exact time of firing the guns since the<br />
firing heads require a predetermined<br />
pressure before the guns can fire<br />
Works with full-opening or non-fullopening<br />
downhole tools<br />
Ideal for balanced or overbalanced<br />
perforating<br />
Can be used for dual completions,<br />
drillstem testing, or production<br />
perforating<br />
Well-suited for highly deviated well<br />
completions<br />
SAP No.<br />
100014211<br />
SAP No.<br />
100005190<br />
100014215<br />
Thread Size <strong>and</strong> Type<br />
in. (mm)<br />
2 7/8 (73.03) EUE 8 Rd Box ×<br />
2 7/8 (73.03) 6P Acme Box<br />
Thread Size <strong>and</strong> Type<br />
in. (mm)<br />
1.90 (48.26) EUE 10 Rd Pin ×<br />
2 3/8 (60.33) 6P Acme Box<br />
2 7/8 (73.03) EUE 8 Rd Box ×<br />
2 7/8 (73.03) 6P Acme Box<br />
Can be run on the top or bottom of<br />
the perforating assembly<br />
Can be easily redressed<br />
Operation<br />
The model K <strong>and</strong> K-II firing heads are<br />
designed to provide a reliable <strong>and</strong> costeffective<br />
method for firing guns using<br />
hydrostatic pressure. Each firing head<br />
contains a firing piston that is shearpinned<br />
in place above an initiator. The<br />
number of shear pins used varies for<br />
each well situation.<br />
When enough hydrostatic pressure is<br />
applied to the piston, the shear pins<br />
shear, thereby allowing the firing pin on<br />
the lower end of the piston to be driven<br />
into the initiator. This action detonates<br />
the guns. These firing heads do not<br />
have a built-in delay.<br />
Model K Firing Head Specifications<br />
Maximum OD<br />
in. (mm)<br />
3.375<br />
(85.73)<br />
Makeup<br />
Length<br />
ft (m)<br />
1.25<br />
(0.38)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
Model K-II Firing Head<br />
5-50 <strong>Perforating</strong> Solutions<br />
13,000<br />
(895)<br />
Model K-II Firing Head Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
2.75<br />
(69.85)<br />
3.375<br />
(85.73)<br />
Makeup<br />
Length<br />
ft (m)<br />
1.24<br />
(0.38)<br />
1.64<br />
(0.50)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
19,500<br />
(1345)<br />
19,500<br />
(1345)<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
4,000<br />
(275)<br />
4,000<br />
(275)<br />
4,000<br />
(275)<br />
HAL15381<br />
Tensile<br />
Strength<br />
lb (kg)<br />
220,000<br />
(99 700)<br />
Tensile Strength<br />
lb (kg)<br />
187,000<br />
(84 800)<br />
220,000<br />
(99 700)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
30,000<br />
(2070)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
25,000<br />
(1725)<br />
30,000<br />
(2070)
Model KV-II Firing Head<br />
The model KV-II firing head makes the<br />
firing of the guns <strong>and</strong> the opening of<br />
the vent one operation rather than two.<br />
This tool allows the operator more<br />
accurate control of when the vent opens<br />
in relation to when the guns fire.<br />
Features<br />
Useful in wells with open<br />
perforations where it is not possible<br />
to pressure up on the wellbore to<br />
actuate a firing head<br />
Useful in perforating <strong>and</strong> stimulation<br />
jobs where the tubing pressure<br />
exceeds the limitations of the casing<br />
Useful because the firing head <strong>and</strong><br />
vent operate at one pressure<br />
Ideal for deviated wells<br />
Piston mechanically locked after<br />
firing<br />
SAP No.<br />
100014153<br />
100014155<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.33) EUE 8 Rd Pin ×<br />
2 3/8 (60.33) 6P Acme Box<br />
2 7/8 (72.88) EUE 8 Rd Pin ×<br />
2 7/8 (72.88) 6P Acme Box<br />
Operation<br />
In many tubing conveyed perforating<br />
applications, it is either desirable or<br />
necessary to keep the tubing closed<br />
until the guns have been detonated. In<br />
the past, the tubing was kept closed by a<br />
firing head with some type of vent<br />
assembly. Coordination between the<br />
two tools was sometimes hard to<br />
achieve, <strong>and</strong> the vent often opened<br />
either too soon or too late. The model<br />
KV-II firing head combines a firing<br />
head <strong>and</strong> a vent assembly.<br />
In the model KV-II firing head, a piston<br />
is sheared to cause the guns to detonate<br />
<strong>and</strong> the ports to open <strong>and</strong> equalize (or<br />
vent) pressure. This venting feature<br />
allows operators to run the tubing in<br />
the hole dry if needed. In the st<strong>and</strong>ard<br />
KV-II firing head, the ports in the tool<br />
open the instant the firing head is<br />
actuated <strong>and</strong> the guns detonate. To<br />
delay the gun detonation, one or more<br />
delay devices may be added to the<br />
assembly.<br />
Model KV-II Firing Head Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
2.75<br />
(69.85)<br />
3.375<br />
(85.73)<br />
Flow Area<br />
in. 2 (cm 2 )<br />
2.79<br />
(18.0)<br />
3.14<br />
(20.27)<br />
Minimum Makeup<br />
Length<br />
ft (m)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
Model KV-II<br />
Firing Head<br />
<strong>Perforating</strong> Solutions 5-51<br />
1.33<br />
(0.41)<br />
1.43<br />
(0.44)<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
25,000<br />
(1725)<br />
25,000<br />
(1725)<br />
HAL15459<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
3,000<br />
(206)<br />
4,000<br />
(275)<br />
Maximum<br />
Differential<br />
Pressure<br />
psi (bar)<br />
15,000<br />
(1035)<br />
15,000<br />
(1035)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
145,000<br />
(65 700)<br />
235,000<br />
(106 600)
Time-Delay Firer<br />
The time-delay firer (TDF) allows<br />
under- or overbalanced perforating<br />
through the use of a pressure-actuated<br />
firing head with a time-delay fuse. The<br />
delay fuse allows 4 to 6 minutes for<br />
adjusting the actuating pressure in the<br />
tubing to achieve the desired pressure<br />
before firing the guns.<br />
Features<br />
Allows independent perforating of<br />
selected zones<br />
Allows maximum use of under- or<br />
overbalanced pressure<br />
Can be run in heavy mud systems<br />
Can be used with full-opening or<br />
non-full-opening tools<br />
Reduces cost by allowing the running<br />
of multiple guns without gun spacers<br />
Ideal for production completions,<br />
drillstem testing, <strong>and</strong> dual<br />
completions<br />
Recommended for running on the<br />
top <strong>and</strong> bottom of gun assemblies<br />
Allows additional time-delay<br />
elements as needed for increasing<br />
delay time<br />
SAP No.<br />
100014157<br />
100005231<br />
100005230<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
1 7/16 (36.51) 8 UN-2 B Box ×<br />
1.315 (33.4) NU-10 Rd Pin<br />
1.90 (48.26) EUE 10 Rd Pin ×<br />
2 (50.8) 6P Acme Box<br />
2 7/8 (73.03) EUE 8 Rd Pin ×<br />
2 7/8 (73.03) 6P Acme Box<br />
Operation<br />
The TDF is run with a predetermined<br />
number of shear pins for specific well<br />
conditions. The tubing is pressured to<br />
the maximum actuating pressure<br />
slowly. The maximum pressure shears<br />
the pins in the shear set <strong>and</strong> forces the<br />
firing piston into the primer. The<br />
primer ignites the pyrotechnic delay<br />
fuse. The delay fuse burns for a<br />
predetermined time (between 4 <strong>and</strong> 6<br />
minutes) depending on the bottomhole<br />
temperature <strong>and</strong> detonates the<br />
perforating assembly.<br />
Time-Delay Firer (TDF) Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
1.688<br />
(42.88)<br />
2.50<br />
(63.5)<br />
3.375<br />
(85.73)<br />
Makeup<br />
Length<br />
ft (m)<br />
2.16<br />
(0.65)<br />
1.69<br />
(0.52)<br />
1.81<br />
(0.55)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
21,500<br />
(1482)<br />
25,000<br />
(1723)<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
Time-Delay<br />
Firer (TDF)<br />
5-52 <strong>Perforating</strong> Solutions<br />
13,000<br />
(895)<br />
Temperature rating is determined by explosives or elastomers.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
2,200<br />
(150)<br />
4,000<br />
(275)<br />
4,000<br />
(275)<br />
HAL15382<br />
Temperature<br />
Rating<br />
°F (°C)<br />
425 (218) for<br />
200 hours<br />
425 (218) for<br />
200 hours<br />
350 (176) for<br />
500 hours<br />
Tensile<br />
Strength<br />
lb (kg)<br />
56,000<br />
(25 400)<br />
120,000<br />
(54 432)<br />
220,000<br />
(99 700)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
26,300<br />
(1813)<br />
30,000<br />
(2070)<br />
30,000<br />
(2070)
Multiaction-Delay Firing Head<br />
The multiaction-delay firing head is a pressure-actuated<br />
redundant firing system that can be run with any one of<br />
several other firing heads.<br />
Features<br />
Allows the use of a redundant firing head without having a<br />
firing head on the bottom of the gun string<br />
Allows multiple redundancy when a multiaction firing<br />
head is placed on both the top <strong>and</strong> bottom of the gun<br />
string<br />
Allows operators to postpone the decision of whether to<br />
use the bar drop or pressure side of the firing head as the<br />
primary firing mechanism<br />
Allows use of additional delay elements<br />
Operation<br />
One side of the multiaction firing head will always be<br />
pressure-actuated. The other side of the firing head may be a<br />
bar drop-type head or another pressure-actuated firing head.<br />
Either side of the firing head may be used as the primary or<br />
backup firing system.<br />
SAP No.<br />
100155753<br />
100155750<br />
Thread Size <strong>and</strong><br />
Type<br />
in. (mm)<br />
2 3/8 (60.33) 6P<br />
Acme Box × Pin<br />
2 7/8 (73.03) 6P<br />
Acme Box × Pin<br />
Multiaction-Delay Firing Head Specifications<br />
Maximum OD<br />
in. (mm)<br />
3.10<br />
(78.74)<br />
3.375<br />
(85.73)<br />
Makeup<br />
Length<br />
ft (m)<br />
3.41<br />
(1.04)<br />
3.41<br />
(1.04)<br />
Maximum Operating<br />
Pressure<br />
psi (bar)<br />
18,000<br />
(1240)<br />
25,000<br />
(1725)<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Multiaction-Delay<br />
Firing Head<br />
<strong>Perforating</strong> Solutions 5-53<br />
HAL10511<br />
Minimum Operating<br />
Pressure<br />
psi (bar)<br />
4,000<br />
(275)<br />
4,000<br />
(275)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
170,000<br />
(77 100)<br />
201,000<br />
(91 100)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
22,000<br />
(1515)<br />
29,000<br />
(2000)
Annulus Pressure Firer-Control Line<br />
The annulus pressure firer-control line<br />
(APF-C) was developed as a dual-firing<br />
system that allows the perforating guns<br />
to be detonated by annular pressure, a<br />
drop bar, or tubing pressure. The<br />
APF-C system consists of a pressure<br />
transfer reservoir, a sleeve through the<br />
packer m<strong>and</strong>rel, an adapter below the<br />
packer, <strong>and</strong> a control line to transmit<br />
pressure from the annulus above the<br />
packer to the APF-C firing head<br />
assembly on top of the guns. Any of the<br />
mechanical or pressure-firing heads can<br />
be attached to the top of the APF-C<br />
firing head.<br />
Features<br />
Can be used with non-full-opening<br />
test tools <strong>and</strong> partially filled tubing<br />
strings<br />
Can be used for drillstem testing or<br />
shoot-<strong>and</strong>-pull for gravel packs<br />
Can be used wherever a pressureactuated<br />
tool is desirable<br />
Ideal for deviated wells<br />
Provides a system of two firing heads<br />
on top of the guns<br />
SAP No.<br />
100156138<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 7/8 (73.03) 6P<br />
Acme Box × Pin<br />
Can be run with a mechanical or<br />
pressure-actuated firing head as a<br />
secondary firing mechanism<br />
Enhances safety because the annulusoperated<br />
portion is pressure balanced<br />
before the packer is set <strong>and</strong> the tester<br />
valve is opened<br />
Operation<br />
The APF-C system depends on the<br />
transfer of annular pressure through<br />
the packer down to the APF-C firing<br />
head. This pressure creates a differential<br />
pressure across the m<strong>and</strong>rel where the<br />
firing piston is housed. When the<br />
predetermined differential pressure is<br />
reached, the pins shear <strong>and</strong> the m<strong>and</strong>rel<br />
moves up <strong>and</strong> releases the firing piston,<br />
which is driven down by rathole<br />
pressure. The piston strikes the firing<br />
pin which detonates the initiator.<br />
The operation of the drop bar or<br />
pressure-actuated firing head depends<br />
on which firing head system is used.<br />
Annulus Pressure Firer-Control Line (APF-C) Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
3.68<br />
(93.47)<br />
Makeup<br />
Length<br />
ft (m)<br />
3.70<br />
(1.13)<br />
Maximum Operating<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Minimum Operating<br />
Pressure<br />
psi (bar)<br />
Annulus Pressure<br />
Firer-Control Line (APF-C)<br />
Firing Head<br />
5-54 <strong>Perforating</strong> Solutions<br />
250<br />
(17)<br />
HAL10515<br />
Tensile<br />
Strength<br />
lb (kg)<br />
174,000<br />
(78 900)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
17,000<br />
(1170)
Annulus Pressure Transfer Reservoir<br />
The annulus pressure transfer reservoir (APTR) is an integral<br />
component of the annulus pressure firer-control line<br />
(APF-C). The APTR is the mechanism that transmits pressure<br />
from above the packer to a differential pressure or pressureactuated<br />
firing (PAF) head on top of the perforating assembly.<br />
Features<br />
Features a full-opening ID<br />
Compatible with mud environments<br />
Adapted for RTTS <strong>and</strong> CHAMP® IV packers<br />
Ideal for applications that require a partial fluid column in<br />
the tubing string<br />
Eliminates the need for nitrogen<br />
Operation<br />
The APTR transmits annulus pressure into a microannulus<br />
created by the packer m<strong>and</strong>rel <strong>and</strong> the APTR<br />
m<strong>and</strong>rel. The pressure is ported to a control-line sub on<br />
the lower end of the packer. A stainless steel control line<br />
connects the APTR to the pressure-responsive firing head<br />
on the perforating assembly.<br />
SAP No.<br />
100156028<br />
101016453<br />
Maximum<br />
OD<br />
in. (mm)<br />
5.00<br />
(127.00)<br />
6.12<br />
(155.45)<br />
Packer Top<br />
Connection<br />
Annulus Pressure<br />
Transfer Reservoir<br />
Annulus Pressure<br />
Transfer Reservoir (APTR)<br />
Annulus Pressure Transfer Reservoir (APTR) Specifications<br />
Minimum<br />
ID<br />
in. (mm)<br />
2.00<br />
(50.8)<br />
2.37<br />
(60.20)<br />
Top<br />
Assembly<br />
3 1/2<br />
4 IF Box x<br />
3 7/8<br />
6 Stub Acme Pin<br />
4 1/2 4 IF<br />
Box x Pin<br />
Lower<br />
Assembly<br />
2 7/8 (73.03)<br />
EUE 8 Rd<br />
Box x Pin<br />
4 1/2 (114.3)<br />
4-IF Box x<br />
3 1/2 (88.90)<br />
EUE 8 Rd Pin<br />
Length Above<br />
Packer<br />
ft (m)<br />
Packer<br />
Bottom<br />
Connection<br />
Lower<br />
Control-Line<br />
Housing<br />
<strong>Perforating</strong> Solutions 5-55<br />
5.09<br />
(1.55)<br />
4.34<br />
(1.32)<br />
Temperature rating is determined by o-rings.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
HAL15439<br />
Length Below<br />
Packer<br />
ft (m)<br />
1.02<br />
(0.31)<br />
1.33<br />
(0.41)<br />
HAL15440<br />
Tensile<br />
Strength<br />
lb (kg)<br />
328,000<br />
(148 700)<br />
587,000<br />
(266 200)<br />
Burst<br />
Pressure<br />
psi (bar)<br />
18,000<br />
(1240)<br />
22,000<br />
(1515)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
15,000<br />
(1035)<br />
19,000<br />
(1310)
Slimhole Annulus Pressure Firer—Internal Control<br />
5-in. Annulus Pressure Transfer Reservoir<br />
The slimhole annulus pressure transfer reservoir (APTR)<br />
system assembles in a similar manner to the 7-in. <strong>and</strong><br />
9 5/8-in. APTR systems. Only two design changes have been<br />
implemented in the new 5-in. APTR system. First, a series of<br />
concentric tubes below the packer replaces the control line<br />
from larger APTR systems. Second, a single tube m<strong>and</strong>rel<br />
runs through the packer, replacing the series of threaded tube<br />
m<strong>and</strong>rels from the larger APTR systems.<br />
3 1/8-in. Internal Control<br />
Concentric tubes eliminate the need for an external control<br />
line in slimhole casing.<br />
3 1/8-in. Annulus Pressure Transfer Reservoir—<br />
Internal Control<br />
The slimhole 3 1/8-in. (APF-IC) firing head is designed for<br />
use with the 5-in. APTR system with internal control. The<br />
firing head design remains the same as the 3 3/8-in. APF-C<br />
with diameter reductions in many of the component parts to<br />
achieve a true 3.13-in. OD.<br />
SAP No.<br />
101301541<br />
Ball Valve<br />
Annular Pressure<br />
Transfer Sub<br />
Safety Joint<br />
Retrievable Packer<br />
Flow Ports<br />
Firing Head<br />
VannGun ®<br />
Assembly<br />
5-56 <strong>Perforating</strong> Solutions<br />
HAL15403<br />
Slimhole Annulus Pressure Firer—<br />
Internal Control (APF-IC)<br />
Installation<br />
Slimhole Annulus Pressure Firer—Internal Control (APF-IC) Specifications<br />
Thread Size<br />
<strong>and</strong> Type<br />
2 3/4-in. 6P<br />
Acme Box × Pin<br />
Max OD<br />
in. (mm)<br />
3.13<br />
(79.5)<br />
Min ID<br />
in. (mm)<br />
1.25<br />
(31.75)<br />
No. of<br />
Ports<br />
2<br />
Makeup<br />
Length<br />
ft (m)<br />
56.41<br />
(17.2)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1378)<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
Temperature Rating 325°F (20K psi) with Extreme Environment Kit (162°C 1.406 kg/cm 2 with Extreme Environment Kit)<br />
Call Technology for temperatures above 325°F (162°C).<br />
250<br />
(17)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
87,000<br />
(39 463)<br />
Burst<br />
Pressure<br />
psi (bar)<br />
N/A<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
10,000<br />
(689)
Differential Firing Head<br />
The differential firing head (DFH) was<br />
designed to allow underbalanced<br />
perforating with a differential pressureactuated<br />
firing system. The DFH works<br />
by requiring the internal pressure to be<br />
greater than the external pressure. This<br />
condition can be created when pressure<br />
is applied to the ID or when the OD<br />
pressure is reduced.<br />
The pressure required to actuate the DFH<br />
may be lower than that used for other<br />
pressure-operated firing heads because it<br />
is operated by differential pressure.<br />
Features<br />
Allows underbalanced perforating in<br />
horizontal wells without a packer<br />
Ideal for perforating with a sucker<br />
rod or submersible pump in place<br />
Offers added safety because it is<br />
pressure-balanced when being run<br />
into the well<br />
Helps allow maximum<br />
underbalanced pressure in lowpressure<br />
wells when mechanical<br />
firing is not desirable<br />
SAP No.<br />
120002262<br />
100014232<br />
Thread Size <strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.33) EUE<br />
8 Rd Box × 2 3/8 (60.33)<br />
6P Acme Box<br />
2 7/8 (73.03) EUE<br />
8 Rd Box ×<br />
2 7/8 (73.03) 6P Acme Box<br />
Can be used when equipment or well<br />
conditions will not permit the use of<br />
high pressures<br />
Allows the use of time-delay elements<br />
as needed<br />
Operation<br />
The DFH is actuated after a<br />
predetermined differential pressure is<br />
created in the firing head ID. This<br />
differential pressure can be created<br />
when surface pressure is applied to the<br />
tubing or by reducing the hydrostatic<br />
pressure in the annulus.<br />
When the predetermined differential<br />
pressure is reached, the shear pins<br />
holding the dog retainer piston will<br />
shear, allowing the dog retainer to<br />
move up. The upward movement<br />
releases the dogs holding the firing<br />
piston in place, <strong>and</strong> the internal<br />
pressure drives the firing piston into<br />
the initiator.<br />
Differential Firing Head (DFH) Specifications<br />
Maximum OD<br />
in. (mm)<br />
3.0<br />
(76.20)<br />
3.38<br />
(85.73)<br />
Makeup<br />
Length<br />
ft (m)<br />
1.94<br />
(0.59)<br />
1.98<br />
(0.60)<br />
Maximum<br />
Operating<br />
Pressure<br />
(Differential)<br />
psi (bar)<br />
Minimum<br />
Operating<br />
Pressure<br />
(Differential)<br />
psi (bar)<br />
Differential Firing Head (DFH)<br />
<strong>Perforating</strong> Solutions 5-57<br />
10,000<br />
(690)<br />
5,000<br />
(345)<br />
Temperature rating is determined by explosives or o-rings.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
1,000<br />
(69)<br />
1,000<br />
(69)<br />
HAL10518<br />
Tensile<br />
Strength<br />
lb (kg)<br />
130,000<br />
(58 900)<br />
220,000<br />
(99 700)<br />
Burst<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)
Hydraulic Actuator Firing Head <strong>and</strong><br />
Swivel-Type Hydraulic Actuator Firing Head<br />
The hydraulic actuator firing head<br />
(HAF) is a pressure-balanced tool that<br />
automatically fills the tubing string<br />
while it is running in the well. A<br />
stainless steel or ceramic ball is dropped<br />
from the surface or circulated into<br />
position. Pressure applied to the tubing<br />
string actuates the HAF.<br />
The smaller swivel-type hydraulic<br />
actuator firing head (SHAF) has a<br />
swivel incorporated into the firing<br />
head assembly. The added swivel<br />
feature allows the lower portion of the<br />
firing head <strong>and</strong> the attached explosive<br />
assembly to rotate independently from<br />
the tubing string.<br />
Features<br />
Allows packerless completions<br />
Makes actuation easily observable<br />
SAP No.<br />
100156011<br />
(Swivel Type)<br />
100156025<br />
101007031<br />
100156150<br />
101313489<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
1.315 (33.40)<br />
NU-10 Rd Pin ×<br />
17/16 (36.51)<br />
8UN-2B Box<br />
1.315 (33.40)<br />
NU-10 Rd Pin ×<br />
17/16 (36.51)<br />
8UN-2B Box<br />
1.90 (48.26) EUE-10 Rd<br />
3/4 TPF Pin<br />
2 3/8 (60.33) 6P Acme<br />
Box<br />
2 3/8 (60.33) EUE<br />
8 Rd Pin ×<br />
2 7/8 (73.03)<br />
6P Acme Box<br />
2 7/8 (73.03) EUE 8 Rd<br />
Pin × 2 7/8 (73.03) 6P<br />
Acme Box<br />
Useful in coiled tubing conveyed<br />
completions, deviated wells, <strong>and</strong><br />
through-tubing perforating<br />
Reusable<br />
Rotation of explosive assembly from<br />
tubing string possible with<br />
swivel type<br />
Operation<br />
A stainless steel or ceramic ball is<br />
dropped from the surface or is<br />
circulated downhole into the hammer<br />
piston. Pressure applied to the tubing<br />
string shears the retaining pins <strong>and</strong><br />
forces the hammer piston into the<br />
firing pin. The firing pin detonates the<br />
initiator, which starts the detonation of<br />
the perforating assembly. Circulation is<br />
regained as soon as the firing pin has<br />
been sheared.<br />
5-58 <strong>Perforating</strong> Solutions<br />
HAL15384<br />
Hydraulic Actuator<br />
Firing Head (HAF)<br />
Hydraulic Actuator Firing Head (HAF) Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
1.69<br />
(42.88)<br />
1.69<br />
(42.88)<br />
2.75<br />
(69.85)<br />
3.38<br />
(85.85)<br />
3.38<br />
(85.85)<br />
Ball OD<br />
in. (mm)<br />
0.625<br />
(15.875)<br />
0.625<br />
(15.875)<br />
0.625<br />
(15.875)<br />
1.375<br />
(34.925)<br />
1.375<br />
(34.925)<br />
No. <strong>and</strong> ID<br />
of Ports<br />
in. (mm)<br />
2 @ 0.5<br />
(12.70)<br />
2 @ 0.5<br />
(12.70)<br />
2 @ 0.5<br />
(12.70)<br />
4 @ 1.0<br />
(25.40)<br />
4 @ 1.0<br />
(25.40)<br />
Flow Area of<br />
Ports<br />
in. 2 (cm 2 )<br />
0.39<br />
(2.52)<br />
0.39<br />
(2.52)<br />
0.39<br />
(2.52)<br />
3.14<br />
(20.26)<br />
3.14<br />
(20.26)<br />
Makeup<br />
Length<br />
ft (m)<br />
2.84<br />
(0.87)<br />
2.18<br />
(0.66)<br />
2.28<br />
(0.691)<br />
2.40<br />
(0.73)<br />
2.40<br />
(0.73)<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Maximum Operating<br />
Pressure (differential)<br />
psi (bar)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
HAL10563<br />
Swivel-Type Hydraulic<br />
Actuator Firing Head (SHAF)<br />
Actuating<br />
Pressure<br />
psi (bar)<br />
3,200<br />
(221)<br />
3,200<br />
(221)<br />
3,200<br />
(221)<br />
2,000<br />
(138)<br />
2,000<br />
(138)<br />
Tensile<br />
Rating<br />
lb (kg)<br />
50,000<br />
(22 680)<br />
50,000<br />
(22 680)<br />
113,000<br />
(51 256)<br />
135,600<br />
(61 507)<br />
216,000<br />
(97 976)
Mechanical Metering Hydraulic-Delay Firing Head<br />
The mechanical metering hydraulic-delay (MMHD) firing<br />
head provides a retrievable firing system with an adjustable<br />
delay for situations where longer delay times are needed.<br />
Delay time can be adjusted from 1 to 6 hours. The tool is<br />
designed with a 1/2 gallon fluid chamber below a weighted<br />
piston. The piston meters downward until it travels into a<br />
larger bore which allows it to free-fall <strong>and</strong> initiate a<br />
mechanical firing head.<br />
Delay time is affected by temperature, tool weight above the<br />
piston, <strong>and</strong> the number of jets used (maximum of two), <strong>and</strong><br />
the adjustments can be made by running one or two fluid<br />
metering jets or by changing the amount of fluid.<br />
Features<br />
Adjustable time-delay—May vary from 1 up to 6 hours<br />
Retrievability—Firing head can be pulled <strong>and</strong> another one<br />
run without affecting the rest of the bottomhole assembly<br />
Safety—With the ability to run the firing head <strong>and</strong> the<br />
guns separately, this system greatly reduces the chance of<br />
accidental or premature firing of guns<br />
Operation<br />
The MMHD assembly is run into the well using normal<br />
monobore completion techniques. The mechanical metering<br />
hydraulic-delay firing head is conveyed on a slickline or<br />
electric line. For safety <strong>and</strong> flexibility, the tool will not start<br />
metering until it is l<strong>and</strong>ed on the top gun. Once in place <strong>and</strong><br />
released, the firing head starts to meter. The running tools<br />
can either be pulled into the lubricator, pulled completely<br />
out of the hole, or simply pulled up the hole to a safe distance<br />
<strong>and</strong> secured to await detonation. After the guns have fired,<br />
the firing head can be quickly relatched <strong>and</strong> retrieved using<br />
the same conveyance methods as during deployment.<br />
SAP No.<br />
101201927<br />
<strong>Perforating</strong> Solutions 5-59<br />
HAL6559<br />
Mechanical Metering Hydraulic-<br />
Delay (MMHD) Firing Head<br />
Mechanical Metering Hydraulic-Delay (MMHD) Firing Head Assembly Specifications<br />
Maximum<br />
OD<br />
in. (cm)<br />
Dependent on<br />
centralizers<br />
Stinger<br />
Fishing<br />
Neck<br />
in. (cm)<br />
1.75<br />
(4.45)<br />
Maximum<br />
Stroke<br />
Length<br />
in. (cm)<br />
54.86<br />
(139.34)<br />
Maximum Metering<br />
Stroke* Length<br />
(Available for Delay)<br />
in. (cm)<br />
46.50<br />
(118.11)<br />
Overall<br />
Length*<br />
(Extended)<br />
ft (m)<br />
12.44<br />
(3.79)<br />
Maximum<br />
Operating<br />
Pressure<br />
(Differential)<br />
psi (bar)<br />
13,000<br />
(896.6)<br />
*Length from top sub to firing head body (does not include weight bars <strong>and</strong>/or skirt)<br />
Delay time of 1 hour minimum is recommended for safe operation of system.<br />
Delay time of 6 maximum hours is dependent on temperature, silicon fluid, <strong>and</strong> number of jets.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Temp<br />
Rating<br />
°F (°C)<br />
350<br />
(176.67)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
51,100<br />
(23 100)<br />
Total<br />
Volume<br />
(Silicon)<br />
gal (liter)<br />
1/2<br />
(1.89)<br />
Assembly<br />
Weight<br />
lb (kg)<br />
152<br />
(68.95)
Slickline-Retrievable Mechanical Firing Head<br />
The slickline-retrievable mechanical<br />
firing head (SLRMFH) is designed to<br />
give customers flexibility in<br />
completing a well. It can be run<br />
attached to the guns, separately from<br />
the guns, or using an auto-release<br />
firing mechanism. The firing head<br />
latches onto the guns <strong>and</strong> provides a<br />
positive indication that it is attached.<br />
The SLRMFH can be retrieved if the<br />
firing head needs to be replaced.<br />
The system can be run with either a<br />
mechanically operated firing head or a<br />
pressure-operated firing head. It is<br />
designed so that 80% of the parts are<br />
used in all three applications allowing<br />
for more flexibility with less inventory.<br />
Features<br />
Saves rig time—If for any reason the<br />
firing head needs replacement, the<br />
guns remain in the hole <strong>and</strong> the<br />
firing head can be retrieved<br />
Positive engagement—When the<br />
firing head is run separately, the<br />
operator can tell when the firing head<br />
is latched onto the guns<br />
Safety—Guns can be run separately<br />
from the firing head adding a safety<br />
feature for the guns at the surface<br />
Flexibility—Guns can be run<br />
separately or attached. Unlimited<br />
number of runs can be made to<br />
replace firing head if needed<br />
Operation<br />
The SLRMFH was designed for 3 1/2-<br />
<strong>and</strong> 2 7/8-in. tubing strings. It can be<br />
run with either a mechanical drop<br />
firing head, or a pressure-operated<br />
firing head such as the 1 11/16 timedelay<br />
firer (TDF).<br />
The top gun is assembled with the J-slot<br />
stinger. The guns are run into the well<br />
on tubing <strong>and</strong> then correlated on<br />
depth. The running tool is latched to<br />
the firing head at surface <strong>and</strong> run in on<br />
wireline/slickline.<br />
As the firing head is lowered, it comes<br />
in contact with the J-slot stinger. The<br />
skirt on the firing head then<br />
automatically latches into position<br />
connecting the firing head with the<br />
J-slot stinger. An overpull is applied to<br />
give a positive latch indication. The<br />
running tool is released by jarring<br />
down <strong>and</strong> the slickline is pulled out of<br />
the well. The guns are fired by pressure<br />
or mechanical means.<br />
The firing head can be retrieved by<br />
relatching to the firing head <strong>and</strong> jarring<br />
up. The jarring action shears the brass<br />
screws freeing the firing head from the<br />
J-slot stinger. If the firing head does not<br />
actuate, another firing head may be run<br />
as many times as required.<br />
Slickline-Retrievable Mechanical<br />
Firing Head (SLRMFH)<br />
5-60 <strong>Perforating</strong> Solutions<br />
HAL6560
w/ Model<br />
III-D<br />
Mechanical<br />
FH<br />
SAP No.<br />
101226902<br />
w/ Pressure<br />
Actuated FH 101227170<br />
w/ Model<br />
III-D<br />
Mechanical<br />
FH <strong>and</strong> Auto<br />
Release<br />
101227212<br />
Slickline-Retrievable Mechanical Firing Head (SLRMFH) Specifications<br />
Maximum<br />
OD<br />
in. (cm)<br />
2.31<br />
(5.87)<br />
2.31<br />
(5.87)<br />
2.31<br />
(5.87)<br />
Minimum<br />
ID<br />
(No-Go)<br />
in. (cm)<br />
1.56<br />
(3.96)<br />
1.56<br />
(3.96)<br />
1.56<br />
(3.96)<br />
Overall<br />
Length<br />
(Max)<br />
ft (m)<br />
20.05<br />
(6.11)<br />
20.05<br />
(6.11)<br />
20.05<br />
(6.11)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
8,000<br />
(550)<br />
17,000<br />
(1170)<br />
8,000<br />
(550)<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
250<br />
(17.2)<br />
2,200<br />
(150)<br />
250<br />
(17.2)<br />
Minimum<br />
Operating<br />
Pressure<br />
Auto Release<br />
psi (bar)<br />
Maximum<br />
Differential<br />
Pressure<br />
Auto<br />
Release<br />
psi (bar)<br />
N/A N/A<br />
N/A N/A<br />
Tensile<br />
Strength<br />
of FH<br />
Body<br />
lb (kg)<br />
30,000<br />
(13 600)<br />
30,000<br />
(13 600)<br />
Maximum<br />
Sustained<br />
Force<br />
Required to<br />
Shear Two<br />
Lugs<br />
lb (kg)<br />
4,000<br />
(1800)<br />
4,000<br />
(1800)<br />
<strong>Perforating</strong> Solutions 5-61<br />
1,500<br />
(100)<br />
Burst <strong>and</strong> collapse pressures are determined by tubing.<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
10,000<br />
(690)<br />
30,000<br />
(13 600)<br />
4,000<br />
(1800)<br />
Weight<br />
lb (kg)<br />
120<br />
(54.4)<br />
100<br />
(45.4)<br />
120<br />
(54.4)
Slickline-Retrievable Time-Delay Firer Firing Head<br />
The slickline-retrievable time-delay firer (TDF) firing head<br />
is a combination of two assemblies: the slickline-retrievable<br />
firing head <strong>and</strong> a 1 11/16-in. TDF firing head. It is a<br />
pressure-actuated firing head with a built-in pyrotechnic<br />
time-delay assembly.<br />
Features<br />
Allows the guns to be run in the hole without any type of<br />
firing mechanism installed<br />
Allows the retrieval <strong>and</strong> reinstallation of a malfunctioning<br />
firing head without pulling the guns<br />
Allows greatly reduced actuating pressures of the firing<br />
head because the firing head does not have to be in place<br />
when the guns are run<br />
Operation<br />
This firing head does not have to be run until after all<br />
pressure testing has been done <strong>and</strong> the heavy fluids have been<br />
displaced, which allows a reduced actuating pressure for the<br />
firing head.<br />
This assembly allows the operator to run guns in the hole on<br />
the end of tubing without a firing head. This assembly can be<br />
run in on slickline <strong>and</strong> attached to the firing head after the<br />
tubing is in the hole. It can also be retrieved on slickline.<br />
SAP No.<br />
100155739<br />
5-62 <strong>Perforating</strong> Solutions<br />
HAL15385<br />
Slickline Retrievable Time-Delay Firer<br />
(TDF) Firing Head<br />
HAL15434<br />
Stinger Assembly<br />
1 11/16-in. Slickline-Retrievable Time-Delay Firer (TDF) Firing Head Specifications<br />
Maximum OD<br />
in. (mm)<br />
1.688<br />
(42.88)<br />
Overall Length<br />
(1 fuse)<br />
ft (m)<br />
3.83<br />
(1.17)<br />
Additional Length<br />
per Fuse<br />
ft (m)<br />
0.87<br />
(0.27)<br />
Temperature<br />
Rating<br />
°F (°C)<br />
425 for 200 hours<br />
(218 for 200 hours)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
17,000<br />
(1170)<br />
The assembly certification sheet which specifies the batch number <strong>and</strong> pin values is supplied with each assembly.<br />
SAP No.<br />
100155952<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.33) EUE 8 Rd Box ×<br />
2 7/8 (73.03) 6P Acme Box<br />
3 3/8-in. Vann Jet Stinger Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
3.38<br />
(85.85)<br />
Burst <strong>and</strong> collapse pressures are determined by h<strong>and</strong>ling sub.<br />
Temperature rating is determined by explosives.<br />
Minimum ID<br />
(No-Go)<br />
in. (mm)<br />
1.37<br />
(34.80)<br />
Makeup Length<br />
with<br />
2-ft Sub<br />
ft (m)<br />
5.37<br />
(1.64)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
None<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
2,200<br />
(150)<br />
Tensile<br />
Strength<br />
(FH Body)<br />
lb (kg)<br />
238,000<br />
(107 900)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
23,000<br />
(1590)<br />
Weight with<br />
2-ft Sub<br />
lb (kg)<br />
73<br />
(33)
Extended Delay Fuses<br />
A delay fuse is an explosive device with a slow-burning fuse.<br />
Extended <strong>and</strong> modular delay fuses add time between the<br />
actuation of the firing head <strong>and</strong> the actual detonation of the<br />
guns. Each delay fuse lasts six minutes at 70°F.<br />
Features<br />
Increases delay time when nitrogen is used to actuate the<br />
firing head to give additional time to bleed the nitrogen<br />
pressure down to the desired level<br />
Allows time for necessary actions to take place downhole<br />
such as increasing pressure to open a pressure-actuated<br />
vent assembly<br />
Operation<br />
The extended delay assemblies contain one delay fuse <strong>and</strong><br />
can be run with any other firing assembly. They are installed<br />
between the firing head <strong>and</strong> the guns.<br />
The modular delays are assembled with the firing head in one<br />
housing <strong>and</strong> become an integral part of the firing system.<br />
The modular delays are used primarily with the multiactiondelay<br />
firing head, the 1 11/16-in. time-delay firer (TDF)<br />
firing head, <strong>and</strong> the slickline-retrievable TDF firing head.<br />
SAP No.<br />
Thread Size <strong>and</strong> Type<br />
in. (mm)<br />
100005229 2 (50.8) 6P Acme Box × Pin<br />
100009426 2 7/8 (73.03) 6P Acme Box × Pin<br />
Extended Delay Fuses Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
2.5<br />
(62.5)<br />
3.375<br />
(85.73)<br />
Makeup<br />
Length<br />
ft (m)<br />
1.10<br />
(0.34)<br />
1.10<br />
(0.34)<br />
Maximum<br />
Operating Pressure<br />
psi (bar)<br />
25,000<br />
(1725)<br />
25,000<br />
(1725)<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Extended Delay Fuses<br />
Assembly<br />
<strong>Perforating</strong> Solutions 5-63<br />
HAL15383<br />
Temperature Rating<br />
Delay Fuse<br />
°F (°C)<br />
425 (218) for 200 hours<br />
425 (218) for 200 hours<br />
Tensile<br />
Strength<br />
lb (kg)<br />
197,000<br />
(89 300)<br />
270,000<br />
(122 400)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
30,000<br />
(2070)<br />
30,000<br />
(2070)
Modular Mechanical Firing Head<br />
The modular mechanical firing head is designed to be a<br />
retrievable firing system utilizing a st<strong>and</strong>ard mechanical<br />
firing head with a specialized drop bar for detonation. This<br />
system will allow the operator the flexibility to run the gun<br />
assemblies independently of the firing system. Once the guns<br />
are in place, the firing head is set on the top module <strong>and</strong><br />
released. The perforation assembly is detonated by use of a<br />
special fluted bar dropped from surface.<br />
The most common application for this system is to be run<br />
with the modular guns in a monobore completion. Special<br />
consideration must be given to job set-up <strong>and</strong> execution to<br />
ensure that this tool functions properly.<br />
Features<br />
Safety—With the ability to run the firing head <strong>and</strong> the<br />
guns separately, this system helps to greatly reduce the<br />
chance of accidental or premature firing of the guns<br />
Retrievability—In the event of a mechanical malfunction,<br />
the firing head can be pulled, <strong>and</strong> another one run without<br />
interfering with the rest of the bottomhole assembly<br />
Applications<br />
The modular mechanical firing head is designed to be run on<br />
slickline <strong>and</strong> set on the top gun in a monobore completion<br />
by use of a JDC hydraulic running tool. The system is<br />
designed with the hammer held above the firing pin with<br />
brass shear screws. The two shear screws are rated at<br />
875 lb each. The tool is actuated by dropping a specifically<br />
designed drop bar fitted for the proper casing. (Do not use a<br />
st<strong>and</strong>ard 1 1/4-in. drop bar.) The bar strikes the stinger with<br />
sufficient force to shear the brass screws <strong>and</strong> drive it into the<br />
firing pin.<br />
The firing pin <strong>and</strong> hammer are pressure balanced; <strong>and</strong><br />
therefore, are not limited to any specific depth <strong>and</strong>/or<br />
hydrostatic pressure beyond the tool specifications.<br />
Modular Mechanical<br />
Firing Head<br />
5-64 <strong>Perforating</strong> Solutions<br />
HAL8325
SAP No.<br />
120021629<br />
Stinger Fishing<br />
Neck 2-in.<br />
Stinger<br />
in. (mm)<br />
1.38<br />
(35.05)<br />
Modular Mechanical Firing Head Specifications<br />
Stinger Fishing<br />
Neck 2 1/2-in.<br />
Stinger<br />
in. (mm)<br />
1.75<br />
(44.45)<br />
*Will vary with skirt<br />
Maximum OD dependent on centralizers used.<br />
Temperature rating is determined by explosives.<br />
Weight dependent on centralizers <strong>and</strong> skirts.<br />
SAP No.<br />
N/A<br />
101227709<br />
120125486<br />
101227719<br />
101227720<br />
Drop Bar Options<br />
Casing <strong>and</strong> Tubing<br />
Size <strong>and</strong> Weight<br />
in./lb (cm/kg)<br />
2 7/8 / 6.4<br />
(7.30 / 2.9)<br />
3 1/2 / 9.2<br />
(8.89 / 4.17)<br />
4 1/2 / 9.5-13.5<br />
(11.43 / 4.3-6.12)<br />
5 / 15-18<br />
(12.7 / 6.80-8.16)<br />
5 1/2 / 15.5-23<br />
(13.97 / 7.03-10.43)<br />
Casing ID<br />
in. (mm)<br />
2.441<br />
(62.0)<br />
2.992<br />
(76.0)<br />
4.090<br />
(103.9)<br />
4.408<br />
(111.9)<br />
4.950<br />
(125.7)<br />
Maximum<br />
Operating Pressure<br />
psi (bar)<br />
13,000<br />
(896.6)<br />
Total Bar<br />
OD<br />
in. (mm)<br />
N/A<br />
2.50<br />
(63.5)<br />
3.75<br />
(95.3)<br />
4.125<br />
(104.8)<br />
4.50<br />
(114.3)<br />
Tensile Strength<br />
lb (kg)<br />
59,000<br />
(26 762)<br />
Overall Length*<br />
in. (mm)<br />
72.30<br />
(1836.42)<br />
Maximum Stroke<br />
Length<br />
in. (mm)<br />
7.88<br />
(200.15)<br />
Skirt-Centralizer Selection Chart<br />
SAP No.<br />
101207195<br />
101201882<br />
101228625<br />
101201884<br />
101226987<br />
101205671<br />
Skirt OD<br />
in. (mm)<br />
Centralizer OD<br />
in. (mm)<br />
Shear Rating<br />
For Brass<br />
lb (kg)<br />
<strong>Perforating</strong> Solutions 5-65<br />
2<br />
(50.8)<br />
2.5<br />
(63.5)<br />
2 3/4<br />
(69.9)<br />
3 1/8<br />
(79.4)<br />
3 3/8<br />
(85.7)<br />
4 5/8<br />
(117.4)<br />
N/A<br />
3.00<br />
(76.2)<br />
101207187<br />
3.50<br />
(88.9)<br />
101207198<br />
3.75<br />
(95.3)<br />
100014297<br />
3.25<br />
(82.6)<br />
101213087<br />
3.50<br />
(88.9)<br />
100014299<br />
3.875<br />
(98.4)<br />
101207193<br />
3.75<br />
(95.3)<br />
100009581<br />
4.00<br />
(10.16)<br />
100156785<br />
4.40<br />
(111.8)<br />
100010177<br />
5.61<br />
(142.5)<br />
100156224<br />
5.75<br />
(146.1)<br />
100156225<br />
1,700<br />
(771)
Side-Pocket M<strong>and</strong>rel Firing Head<br />
The side-pocket m<strong>and</strong>rel firing head (SPMFH) is designed<br />
for well conditions that preclude the use of a pressureactuated<br />
firing head run with a Y-block. The side-pocket<br />
m<strong>and</strong>rel firing system is used on single-string, multizone<br />
completions <strong>and</strong> st<strong>and</strong>ard dual completions. A modified<br />
model III-D mechanical firing head is attached to the short<br />
string side of a side-pocket m<strong>and</strong>rel. The firing head is<br />
detonated with a kickover tool run on slickline.<br />
Features<br />
Selectively fires multiple intervals<br />
Eliminates the need for nitrogen<br />
Allows maximum underbalance for low-pressure<br />
formations<br />
Offers economical value<br />
Operation<br />
The model III-D mechanical firing head is made up on the<br />
short string side of the side-pocket m<strong>and</strong>rel. When the<br />
perforating assembly is ready to be detonated, the operator<br />
runs a kickover tool down the long string on slickline. After<br />
the kickover tool is located in the side-pocket m<strong>and</strong>rel, the<br />
slickline operator jars down. The kickover tool hits the<br />
releasing pin on the model III-D. The firing piston is forced<br />
into the initiator by the hydrostatic pressure in the tubing<br />
string to detonate the VannGun® assembly.<br />
5-66 <strong>Perforating</strong> Solutions<br />
HAL15453<br />
Side-Pocket M<strong>and</strong>rel<br />
Firing Head (SPMFH)<br />
Side-Pocket M<strong>and</strong>rel Firing Head (SPMFH) Specifications<br />
SAP No.<br />
100155737<br />
(Firing Head)<br />
221.00284<br />
(7-in. Side-Pocket M<strong>and</strong>rel)<br />
221.00285<br />
(9.625-in. Side-Pocket M<strong>and</strong>rel)<br />
Thread Size <strong>and</strong> Type<br />
(Long String Side)<br />
in. (mm)<br />
1.90 (48.26) EUE 10 Rd Pin<br />
× 2 3/8 (60.33) 6P Acme Box<br />
2 3/8 (60.33) 4.7 lb<br />
OECO-B Box × Box<br />
2 3/8 (60.33) 4.7 lb<br />
OECO-B Box × Box<br />
101306060 3 1/2 CJ Hydril<br />
Maximum OD<br />
in. (mm)<br />
2.75<br />
(69.85)<br />
5.54<br />
(140.72)<br />
6.62<br />
(168.15)<br />
8.00<br />
(203.20)<br />
Minimum ID<br />
in. (mm)<br />
N/A<br />
1.926<br />
(48.92)<br />
1.926<br />
(48.92)<br />
Overall<br />
Length<br />
ft (m)<br />
2.36<br />
(0.72)<br />
5.79<br />
(1.76)<br />
5.79<br />
(1.76)<br />
N/A N/A<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.
Annulus Pressure Crossover Assembly<br />
The annulus pressure crossover assembly (APCA) allows the<br />
use of annulus pressure to actuate any one of several firing<br />
heads. This assembly is compatible with retrievable packers<br />
of all types <strong>and</strong> sizes.<br />
Features<br />
May be used as the annulus firing system on wells with<br />
non-full-opening test tools <strong>and</strong> a partially filled drillstring<br />
May be used as the annulus firing system on horizontal<br />
wells<br />
Allows the use of below-packer venting devices along with<br />
this assembly<br />
Note: Not recommended for mud environment<br />
Operation<br />
The APCA creates a pressure chamber above the firing head<br />
that is equalized with the pressure in the casing annulus.<br />
Once the packer has been set, the pressure on the annulus<br />
can be increased to actuate a pressure-actuated firing head.<br />
The pressures in the annulus <strong>and</strong> the tubing can also be<br />
manipulated to create the differential pressure necessary to<br />
actuate a differential-type firing head.<br />
SAP No.<br />
100014175<br />
100155786<br />
101241465<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.33)<br />
EUE 8 Rd<br />
2 7/8 (73.03)<br />
EUE 8 Rd<br />
3 1/2 (88.9) API<br />
IF Tool Joint<br />
Annulus Pressure<br />
Crossover Assembly<br />
Packer<br />
Ported Sealing Sub<br />
Tubing<br />
Time-Delay Firer<br />
®<br />
VannGun<br />
Assembly<br />
Annulus Pressure Crossover Assembly (APCA)<br />
Annulus Pressure Crossover Assembly (APCA) Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
3.56<br />
(90.42)<br />
5.0<br />
(127)<br />
5.015<br />
(127.381)<br />
Minimum<br />
ID<br />
Non-fullbore<br />
Non-fullbore<br />
Non-fullbore<br />
Flow Area<br />
in.² (cm²)<br />
2.25<br />
(14.52)<br />
4.75<br />
(30.65)<br />
4.75<br />
(30.65)<br />
<strong>Perforating</strong> Solutions 5-67<br />
HAL15448<br />
Minimum<br />
Makeup<br />
Length<br />
ft (m)<br />
9.15<br />
(2.79)<br />
9.40<br />
(2.87)<br />
9.40<br />
(2.87)<br />
Overall<br />
Length<br />
ft (m)<br />
12.35<br />
(3.76)<br />
12.60<br />
(3.84)<br />
12.60<br />
(3.84)<br />
Maximum operating pressure is determined by tubulars.<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Maximum<br />
Differential<br />
Pressure<br />
psi (bar)<br />
10,000<br />
(689)<br />
9,500<br />
(655)<br />
10,500<br />
(723)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
104,000<br />
(47 173)<br />
145,000<br />
(65 770)<br />
145,000<br />
(65 770)<br />
HAL15449<br />
Burst<br />
Pressure<br />
psi (bar)<br />
11,200<br />
(772)<br />
10,500<br />
(723)<br />
13,210<br />
(910)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
11,700<br />
(806)<br />
11,100<br />
(765)<br />
22,500<br />
(1551)
EZ Cycle Multi-Pressure Cycle Firing Head<br />
The EZ Cycle firing head is a pressure-operated tool that<br />
can be cycled several times prior to firing the perforating<br />
guns. Several pressure operations can also be performed on<br />
the well including tubing testing, packer setting, <strong>and</strong> packer<br />
testing prior to firing the perforating guns. Even if pressure<br />
operations are higher than the operating pressure of the<br />
firing head, the EZ Cycle firing head should not fire until it<br />
has completed all of the preset cycles. The firing head is<br />
cycled by applying pressure at the tool to overcome a<br />
nitrogen-charged chamber which operates the cycling piston<br />
back <strong>and</strong> forth until the entire release rod has been pulled<br />
from the piston collet.<br />
Each EZ Cycle firing head assembly includes a nitrogen<br />
chamber, cycling grapple piston, <strong>and</strong> firing piston with firing<br />
pin initiator assembly.<br />
Features<br />
Ideal for completions <strong>and</strong> drillstem testing<br />
Time-delay elements can be used as needed for delay time<br />
Can be used in underbalanced or overbalanced perforating<br />
jobs<br />
It is a surface-safe firing head because it requires pressure<br />
to energize the firing piston<br />
Operates at low pressure<br />
Can be deployed connected to the gun assembly or run<br />
separate on slickline or coiled tubing<br />
Allows the retrieval <strong>and</strong> reinstallation of a malfunctioning<br />
firing head without pulling the guns<br />
Can be used when equipment or well conditions will not<br />
permit the use of high pressures<br />
EZ Cycle Firing Head Assembly<br />
5-68 <strong>Perforating</strong> Solutions<br />
HAL14095
Operating the EZ Cycle Firing Head<br />
The tool is run in hole with a pre-charged nitrogen chamber,<br />
which is set according to the maximum bottomhole pressure.<br />
After positioning gun on depth <strong>and</strong> all operations prior to<br />
firing guns have been completed, the firing head is cycled to<br />
detonate the perforating guns. Pressure applied at the tool<br />
will move the cycle piston <strong>and</strong> traveling grapple up 0.375 in.<br />
pulling the release rod up 0.375 in. Releasing the applied<br />
pressure will allow the nitrogen charge to move the cycle<br />
Upper<br />
Connection<br />
(External<br />
Fishneck)<br />
in. (cm)<br />
2.313<br />
(5.875)<br />
Lower<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (cm)<br />
2 3/8<br />
(6.0325) 6P<br />
Acme Box<br />
piston <strong>and</strong> traveling grapple down engaging another<br />
0.375 in. of the release rod. These steps are continued until<br />
the release rod is completely retrieved from the firing piston<br />
collet. At this point, the bottomhole pressure will drive the<br />
firing piston into the firing pin detonating the initiator <strong>and</strong><br />
the guns.<br />
3.00 in. Multi-Pressure Cycle Firing Head Assembly Specifications<br />
Makeup<br />
Length<br />
in. (cm)<br />
77.32<br />
(196.393)<br />
Maximum<br />
OD<br />
in. (cm)<br />
3.00<br />
(7.62)<br />
Minimum<br />
ID<br />
in. (cm)<br />
N/A<br />
*Call your local <strong>Halliburton</strong> representative if conditions exceed this value.<br />
Temperature<br />
Rating<br />
°F (°C)<br />
400<br />
(204.4)<br />
Operating Pressure Range<br />
psi (bar)<br />
Low<br />
Pressure<br />
Assembly<br />
1,000-5,000<br />
(68.95-<br />
344.74)<br />
High<br />
Pressure<br />
Assembly<br />
5.000-<br />
20,000<br />
(344.74-<br />
1378.95)<br />
Tensile<br />
Rating*<br />
lb (kg)<br />
100,000<br />
(18 143)<br />
Burst<br />
Pressure*<br />
psi (bar)<br />
40,000<br />
(1379)<br />
Collapse<br />
Rating*<br />
psi (bar)<br />
<strong>Perforating</strong> Solutions 5-69<br />
40,000<br />
(1379)
Pump-Through Firing Head<br />
The 1 11/16-in. pump-through firing head is designed to be<br />
run on coiled tubing <strong>and</strong> is used for breaking the ceramic<br />
flapper valve disk on a one-trip coiled tubing operation. The<br />
firing head originates from proven technology in the<br />
1 11/16-in. pressure actuated pressure firing head. The<br />
components were hardened to withst<strong>and</strong> pumping erosion,<br />
<strong>and</strong> an outer tube is incorporated to allow fluid circulation to<br />
the bottom of the tool. A miniature shaped charge is set in<br />
the bottom of the firing head to shoot into the ceramic disk.<br />
The assembly is actuated by dropping a ball through the<br />
coiled tubing, which seats in the assembly to allow a pressure<br />
differential to actuate the firing head <strong>and</strong> shape charge.<br />
Application<br />
The pump-through firing head can be used to circulate<br />
debris off of a barrier, such as a ceramic disk, <strong>and</strong> then shoot<br />
into the barrier to break it up. This function is primarily<br />
developed toward circulating s<strong>and</strong> <strong>and</strong> other debris off of a<br />
ceramic disk in a production well, <strong>and</strong> then shooting into the<br />
disk to allow access below.<br />
Thread Size <strong>and</strong><br />
Type<br />
in. (mm)<br />
1.315 (33.40)<br />
NU-10RD Pin<br />
Maximum OD<br />
in. (mm)<br />
2.3<br />
(58.42)<br />
Minimum ID*<br />
in. (mm)<br />
0. 44<br />
(11.18)<br />
*Through ball seat<br />
Minimum Operating Pressure is not applicable.<br />
Burst Pressure is not applicable.<br />
Pump-Through Firing Head Specifications<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
3,000 (207)<br />
± 10% at 70°F<br />
Flow Area<br />
(before firing)<br />
in. 2 (mm 2 )<br />
0.15<br />
(96.77)<br />
Temperature<br />
Rating<br />
As per<br />
explosives<br />
Axial Load<br />
Rating<br />
lb (kg)<br />
54,400<br />
(24 700)<br />
Firing Head Assembly<br />
1 11/16-in. Pump Through<br />
5-70 <strong>Perforating</strong> Solutions<br />
HAL15777<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
23,200<br />
(1600)<br />
Overall<br />
Length<br />
in. (mm)<br />
22.69<br />
(576.32)<br />
Mass<br />
lb (kg)<br />
16.9<br />
(7.68)<br />
Maximum Flow<br />
Rate<br />
bbl/min (m 3 /min)<br />
2.5<br />
(0.397)
Ancillary Equipment<br />
Fill Disk Assembly<br />
The fill disk assembly (FDA) is used<br />
where either packer selection or well<br />
conditions preclude the use of a venting<br />
device. The FDA is used in place of a<br />
perforated sub <strong>and</strong> replaces the<br />
balanced isolation tool (BIT) in wells<br />
with reasonably clean fluids. The glass<br />
disk prevents debris from settling on<br />
the firing head. Pressure is equalized<br />
across the glass disk.<br />
The FDA is run between the firing head<br />
<strong>and</strong> packer. The recommended<br />
minimum distance from the FDA to the<br />
firing head is 30 ft (9.14 m).<br />
Features<br />
Allows debris to be circulated off the<br />
glass disk through the flow ports<br />
above the glass disk<br />
Acts as a perforated sub for<br />
circulating fluid displacement with<br />
nitrogen <strong>and</strong> swabbing<br />
Can be run with either a mechanical<br />
or pressure-actuated firing head<br />
SAP No.<br />
100005295<br />
100005297<br />
100005299<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.33) EUE<br />
8 Rd Box × Pin<br />
2 7/8 (73.03) EUE<br />
8 Rd Box × Pin<br />
3 1/2 (88.90) EUE<br />
8 Rd Box × Pin<br />
Operation<br />
The FDA consists of a ported housing<br />
with a glass disk installed in the ID<br />
across the lower set of ports. The disk is<br />
not sealed, so pressure can equalize<br />
across the glass. Any debris falling out<br />
of the tubing or fluid above the glass<br />
should l<strong>and</strong> on the glass disk. This<br />
debris can be circulated off the disk, or<br />
if it is not a large amount, it will be<br />
displaced out the ports by the<br />
detonating bar falling through it.<br />
Once the bar breaks through the disk, it<br />
should fall in clean fluid all the way to<br />
the firing head. In mud systems or wells<br />
with a known debris problem, the<br />
balanced isolation tool is recommended<br />
in place of the FDA.<br />
Fill Disk Assembly (FDA) Specifications<br />
Maximum OD<br />
in. (mm)<br />
3.01<br />
(76.45)<br />
3.51<br />
(89.15)<br />
4.20<br />
(106.68)<br />
Minimum ID<br />
in. (mm)<br />
1.98<br />
(50.29)<br />
2.44<br />
(61.98)<br />
3.0<br />
(76.20)<br />
Flow Area<br />
in.² (cm²)<br />
6.28<br />
(40.54)<br />
Number of<br />
Ports<br />
Fill Disk Assembly<br />
(FDA)<br />
<strong>Perforating</strong> Solutions 5-71<br />
7.88<br />
(50.8)<br />
14.13<br />
(91.20)<br />
8<br />
8<br />
8<br />
HAL8352<br />
Tensile Strength<br />
lb (kg)<br />
120,000<br />
(54 431)<br />
150,000<br />
(68 039)<br />
200,000<br />
(90 718)<br />
Makeup Length<br />
ft (m)<br />
0.76<br />
(0.23)<br />
0.71<br />
(0.22)<br />
0.69<br />
(0.21)
Balanced Isolation Tool<br />
The balanced isolation tool (BIT)<br />
assembly is used where either packer<br />
selection or well conditions preclude the<br />
use of a venting device. The BIT<br />
assembly replaces the fill disk assembly<br />
<strong>and</strong> is used in place of a perforated sub.<br />
The BIT helps prevent contamination of<br />
the fluid below it from the fluid above it.<br />
Debris or solids in the fluid above<br />
should not pass through the glass disk<br />
that is in the floating piston. The glass<br />
disk helps prevent debris from setting on<br />
the firing head. Pressure is balanced<br />
across the glass barrier through<br />
equalizing ports in the piston.<br />
The BIT assembly is run between the<br />
firing head <strong>and</strong> packer. The<br />
recommended minimum distance<br />
from the BIT to the firing head is<br />
30 ft (9.14 m).<br />
Features<br />
Allows mud <strong>and</strong> debris to be<br />
circulated off the glass barrier<br />
through the flow ports above the<br />
glass barrier<br />
Allows displacement of the tubing<br />
with a lighter fluid or nitrogen before<br />
firing the guns<br />
Allows swabbing of the tubing to<br />
achieve differential pressure<br />
Allows stopping <strong>and</strong> circulating at<br />
any depth since flow ports are<br />
always open<br />
Can be run with either a mechanical<br />
or pressure-actuated firing head<br />
Operation<br />
The basic components of the BIT are a<br />
floating piston with a glass disk, a<br />
ported lower housing, <strong>and</strong> a top<br />
housing. The BIT is run with clean fluid<br />
below it.<br />
The upward travel of the floating piston<br />
is limited by the bottom of the top sub.<br />
A pressure increase above the glass<br />
barrier causes the piston to move down<br />
<strong>and</strong> forces fluid below the glass barrier<br />
out of the bleeder ports. A pressure<br />
increase below the glass barrier forces<br />
the piston to move up or forces fluid<br />
out of the bleeder ports.<br />
The piston moves up or down within its<br />
limits to help prevent the glass barrier<br />
from breaking. The glass barrier<br />
remains intact until the bar passes<br />
through it. As fluid enters or leaves the<br />
tubing through the ports, debris on the<br />
glass barrier is washed off.<br />
Balanced Isolation Tool<br />
(BIT)<br />
5-72 <strong>Perforating</strong> Solutions<br />
HAL15460
SAP No.<br />
120022203<br />
101318220<br />
100014322<br />
100014323<br />
100156936<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
1.90 (48.26) EUE<br />
10 Rd Box × Pin<br />
2 3/8 (60.33) EUE<br />
8 Rd Box × Pin<br />
2 3/8 (60.33) EUE<br />
8 Rd Box × Pin<br />
2 7/8 (73.03) EUE<br />
8 Rd Box × Pin<br />
3 1/2 (88.90) EUE<br />
8 Rd Box × Pin<br />
Balanced Isolation Tool (BIT) Specifications<br />
Maximum OD<br />
in. (mm)<br />
2.50<br />
(63.50)<br />
2.895<br />
(73.4)<br />
3.10<br />
(78.74)<br />
3.75<br />
(95.25)<br />
4.25<br />
(107.95)<br />
Minimum ID<br />
in. (mm)<br />
1.61<br />
(40.89)<br />
1.99<br />
(50.54)<br />
1.99<br />
(50.54)<br />
2.44<br />
(61.98)<br />
3.0<br />
(76.20)<br />
<strong>Perforating</strong> Solutions 5-73<br />
No. of<br />
Ports<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
4<br />
4<br />
4<br />
4<br />
4<br />
Total Flow<br />
Area<br />
in. 2 (cm 2 )<br />
2.03<br />
(13.10)<br />
3.09<br />
(19.96)<br />
3.14<br />
(20.27)<br />
4.68<br />
(30.19)<br />
7.07<br />
(45.60)<br />
Overall<br />
Length<br />
ft (m)<br />
2.09<br />
(0.64)<br />
2.02<br />
(0.62)<br />
2.15<br />
(0.65)<br />
2.41<br />
(0.73)<br />
2.41<br />
(0.73)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
110,000<br />
(49 800)<br />
100,000<br />
(45 300)<br />
155,000<br />
(70 200)<br />
200,000<br />
(90 700)<br />
280,000<br />
(126 000)
Ratchet Gun Connector<br />
In addition to perforating new wells, <strong>Halliburton</strong>’s ratchet<br />
gun connector system is ideal for reperforating producing<br />
wells since the well does not have to be killed <strong>and</strong> can be left<br />
on production. It also allows perforating with all production<br />
equipment in place. Connections are made inside the<br />
lubricator using a left-h<strong>and</strong> quick connect<br />
locking mechanism.<br />
Features<br />
Can be snubbed into <strong>and</strong> retrieved from a live well<br />
Utilizes st<strong>and</strong>ard blowout preventers<br />
Can perforate long <strong>and</strong> multiple intervals in a single trip<br />
Does not have to kill producing zone to run or<br />
retrieve guns<br />
Perforates new wells<br />
Reperforates producing wells with all production<br />
equipment in place<br />
Perforates underbalanced or overbalanced assemblies<br />
VannGun® sections are quickly connected together<br />
Can be used with hydraulic workover (HWO)<br />
SAP No.<br />
101000794<br />
101000793<br />
Thread Size <strong>and</strong><br />
Type<br />
in. (mm)<br />
2 3/8 (60.33)<br />
6P Acme Box × Pin<br />
2 7/8 (73.03)<br />
6P Acme Box × Pin<br />
Ratchet Gun Connector<br />
Assembly Using Sealed<br />
Imitation Assembly<br />
Ratchet Gun Connector Specifications<br />
Maximum OD<br />
in. (mm)<br />
2.35<br />
(59.69)<br />
3.375<br />
(85.73)<br />
Makeup Length<br />
ft (m)<br />
2.11<br />
(0.64)<br />
2.11<br />
(0.64)<br />
Ratchet Gun Connector<br />
Assembly Using Non-<br />
Sealed Insert Assembly<br />
5-74 <strong>Perforating</strong> Solutions<br />
HAL22573<br />
Maximum Operating<br />
Pressure<br />
psi (bar)<br />
13,000<br />
(896)<br />
13,000<br />
(896)<br />
Temperature rating is determined by explosive.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
HAL22574<br />
Tensile Strength<br />
lb (kg)<br />
100,000<br />
(45 360)<br />
220,000<br />
(100 000)
AutoLatch Release Gun Connector<br />
The AutoLatch release gun<br />
connector is designed to join<br />
VannGun® assemblies <strong>and</strong> enables<br />
VannGun sections to be run in <strong>and</strong><br />
out of new or producing wells.<br />
Using the AutoLatch system, VannGun<br />
assemblies are connected without<br />
rotation <strong>and</strong> can be operated with<br />
st<strong>and</strong>ard blowout preventer (BOP)<br />
rams, making this connector ideal for<br />
snubbing guns into <strong>and</strong> out of the<br />
wellbore with coiled tubing or a<br />
hydraulic workover (HWO) unit.<br />
The AutoLatch connector can also be<br />
used to run VannGun assemblies on<br />
wireline when the length of the<br />
perforating assembly is limited by the<br />
lubricator length. The VannGun<br />
assemblies can be run in sections<br />
(limited by the weight rating of the<br />
wireline) <strong>and</strong> then, retrieved in<br />
sections. This system reduces the<br />
number of wireline runs to perforate<br />
longer intervals.<br />
SAP No.<br />
Features<br />
Can be used to perforate new or<br />
existing wells<br />
Can snub VannGun assemblies into<br />
<strong>and</strong> out of the well<br />
Utilizes st<strong>and</strong>ard BOPs<br />
Can be used with coiled tubing,<br />
HWO, or wireline<br />
Can retrieve VannGun assemblies<br />
without killing a producing zone<br />
Can perforate in underbalanced or<br />
overbalanced conditions<br />
May be used for monobore<br />
completions<br />
Can be used when oriented<br />
perforations are required<br />
Sections are quickly connected for<br />
time savings<br />
Can be designed to accommodate<br />
different BOP configuration<br />
AutoLatch Release Gun Connector Specifications<br />
Thread Size <strong>and</strong><br />
Type<br />
in. (mm)<br />
Upper<br />
Assembly:<br />
101205866 2 3/8 (60.33)<br />
Lower<br />
Assembly:<br />
101205878<br />
6P Acme Box × Pin<br />
Upper<br />
Assembly:<br />
100155775 2 7/8 (73.03)<br />
Lower<br />
Assembly:<br />
101207115<br />
6P Acme Box × Pin<br />
Maximum<br />
OD<br />
in. (mm)<br />
2.88<br />
(73.15)<br />
3.625<br />
(92.00)<br />
Makeup<br />
Length<br />
ft (m)<br />
4.46<br />
(1.36)<br />
3.47<br />
(1.06)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
80,000<br />
(35 000)<br />
125,000<br />
(56 800)<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Stop/Release<br />
Pads<br />
Spring Housing<br />
Operating Spring<br />
Shear Screws<br />
Stinger Assembly<br />
Collet Fingers<br />
Collet Retainer<br />
Housing<br />
OD Seal Area<br />
Pressure Isolation<br />
Configuration<br />
<strong>Perforating</strong> Solutions 5-75<br />
HAL8662<br />
AutoLatch Release<br />
Gun Connector
Isolation Sub-Assembly<br />
The isolation sub-assembly (ISA) is live<br />
well intervention technology designed<br />
to provide extreme flexibility in well<br />
completions. The ISA allows<br />
completion or recompletion of the well<br />
without killing it. The well can be<br />
producing before, during, <strong>and</strong> after the<br />
guns are deployed in or out of the well.<br />
The ISA is a lower cost alternative to<br />
other live well intervention assemblies.<br />
The ISA incorporates a threaded<br />
connection that is manually connected<br />
<strong>and</strong> disconnected.<br />
SAP No.<br />
101228396<br />
101222274<br />
101226330<br />
Features<br />
Can run VannGun® assemblies on<br />
hydraulic workovers, coiled tubing,<br />
or wireline<br />
Can run VannGun sections to<br />
perforate a new well or add<br />
perforations to existing zones<br />
Can run or retrieve guns without<br />
killing the well<br />
Can perforate underbalanced or<br />
overbalanced<br />
Low cost<br />
Provides extreme flexibility in well<br />
completions<br />
Isolation Sub-Assembly Specifications<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
1 11/16-in.<br />
(42.86)<br />
8P Stub Acme<br />
2G<br />
2 3/8 (60.33)<br />
6P Acme 2G<br />
2 7/8 (73.03)<br />
6P Acme 2G<br />
OD Isolation<br />
Sub-Assembly<br />
with OD Ram<br />
Lock<br />
in. (mm)<br />
2 with 1 1/2<br />
(50.8 with 38.1)<br />
2 3/4 with 2<br />
(69.85 with 50.8)<br />
3 3/8 with 2<br />
(85.73 with 50.8)<br />
Maximum<br />
OD<br />
in. (mm)<br />
2.015<br />
(51.18)<br />
2.765<br />
(70.23)<br />
3.395<br />
(86.23)<br />
Overall<br />
Length<br />
ft (m)<br />
2.42<br />
(0.74)<br />
2.28<br />
(0.69)<br />
2.22<br />
(0.68)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
10,000<br />
(689)<br />
10,000<br />
(689)<br />
10,000<br />
(689)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
64,500<br />
(29 250)<br />
108,000<br />
(49 000)<br />
191,400<br />
(86 800)<br />
Temperature rating is determined by explosive.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
5-76 <strong>Perforating</strong> Solutions<br />
Gun<br />
Isolation<br />
Sub-Assembly<br />
HAL6151<br />
Isolation Sub-Assembly<br />
Sealing<br />
Initiator<br />
Sealing<br />
Area<br />
Sealing<br />
Initiator<br />
Gun
Quick Torque Connector<br />
The Quick Torque connector consists of connectors that<br />
cover both ends of each gun section to enclose the assembly.<br />
The connectors have a common, self-aligning drillpipe<br />
thread that allows automatic or manual makeup. Explosive<br />
transfer occurs through a web, making the system<br />
self-contained for added safety. With these connectors, TCP<br />
gun assemblies can now be picked up by the rig equipment<br />
<strong>and</strong> properly made up using iron roughneck equipment<br />
without the need for human intervention. It simplifies the<br />
process <strong>and</strong> saves time by eliminating assembly of the<br />
components on the rig.<br />
Features<br />
St<strong>and</strong>ard NC38 thread makeup procedure<br />
Redressable<br />
Self-contained system increases personnel safety on the rig<br />
floor—no human intervention is needed<br />
Once the thread protectors are removed, all subsequent<br />
steps can be automated<br />
Efficient, automated system saves rig time<br />
Allows venting of any built-up pressure during shipping<br />
No exposed explosives<br />
Q125 material, sour service > 175° F<br />
Operation<br />
This system can be used on any rig with automatic or manual<br />
pipe h<strong>and</strong>ling equipment. It can be used with 4 5/8-in.<br />
st<strong>and</strong>ard or 4 5/8-in. self-orienting TCP gun systems, <strong>and</strong> a<br />
3 3/8-in.-OD or smaller firing head.<br />
<strong>Perforating</strong> Solutions 5-77<br />
HAL14398<br />
Firing Head<br />
Sub-Assembly<br />
HAL14399<br />
Gun<br />
Sub-Assembly
SAP No.<br />
101635158<br />
101634159<br />
Thread<br />
Connection<br />
Box Modified<br />
API-NC26<br />
Pin Modified<br />
API-NC26<br />
Tool Maximum<br />
OD<br />
in. (mm)<br />
3.14<br />
(79.95)<br />
3.14<br />
(79.95)<br />
Quick Torque Connector - 2 7/8-in. Guns<br />
Maximum Operating<br />
Pressure*<br />
psi (bar)<br />
22,000<br />
(1516)<br />
22,000<br />
(1516)<br />
Temperature<br />
Rating*<br />
°F (°C)<br />
Determined by<br />
explosives <strong>and</strong><br />
elastomers<br />
Determined by<br />
explosives <strong>and</strong><br />
elastomers<br />
*Maximum Operating Pressure <strong>and</strong> Temperature Rating based on the elastomers.<br />
SAP No.<br />
101351984<br />
101352042<br />
101351885<br />
101354907<br />
101381170<br />
Thread<br />
Connection<br />
Pin Connector<br />
Assy, NC38 Pin<br />
x Acme Pin<br />
Firing Head<br />
Connector Assy,<br />
NC38 Pin x<br />
Double Acme<br />
Pin<br />
Box Connector<br />
Assy, NC38 Box<br />
x Acme Pin<br />
Crossover,<br />
St<strong>and</strong>ard NC38<br />
Box x Modified<br />
NC38 Pin<br />
Firing Head<br />
Connector Assy,<br />
Firing Head on<br />
Bottom, NC38<br />
Box x Double<br />
Acme Pin<br />
Tool Max. OD<br />
in. (mm)<br />
4.75<br />
(120.65)<br />
4.75<br />
(120.65)<br />
4.75<br />
(120.65)<br />
4.75<br />
(120.65)<br />
4.75<br />
(120.65)<br />
Makeup<br />
Length<br />
in. (mm)<br />
End Connections<br />
Tensile Rating<br />
lb (kg)<br />
5-78 <strong>Perforating</strong> Solutions<br />
12.5<br />
(317)<br />
9.3<br />
(236)<br />
Quick Torque Connector - 4 5/8-in. Guns<br />
Maximum Operating<br />
Pressure*<br />
psi (bar)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
Temperature<br />
Rating*<br />
°F (°C)<br />
Determined by<br />
explosives <strong>and</strong><br />
elastomers<br />
Determined by<br />
explosives <strong>and</strong><br />
elastomers<br />
Determined by<br />
explosives <strong>and</strong><br />
elastomers<br />
Determined by<br />
explosives <strong>and</strong><br />
elastomers<br />
Determined by<br />
explosives <strong>and</strong><br />
elastomers<br />
*Maximum Operating Pressure <strong>and</strong> Temperature Rating based on the elastomers.<br />
SAP No.<br />
101514211<br />
101535542<br />
101514214<br />
Thread<br />
Connection<br />
Box Modified<br />
API-NC38<br />
Box for<br />
Centralizer<br />
Modified API-<br />
NC38<br />
Pin Modified<br />
API-NC38<br />
Tool Maximum<br />
OD<br />
in. (mm)<br />
5.0<br />
(127)<br />
5.0<br />
(127)<br />
5.0<br />
(127)<br />
Makeup<br />
Length<br />
in. (mm)<br />
6.75<br />
(171)<br />
7.61<br />
(193)<br />
23.08<br />
(586)<br />
13.56<br />
(344)<br />
23.08<br />
(586)<br />
Quick Torque Connector - 5-in. Guns<br />
Maximum Operating<br />
Pressure*<br />
psi (bar)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
Temperature<br />
Rating*<br />
°F (°C)<br />
Determined by<br />
explosives <strong>and</strong><br />
elastomers<br />
Determined by<br />
explosives <strong>and</strong><br />
elastomers<br />
Determined by<br />
explosives <strong>and</strong><br />
elastomers<br />
*Maximum Operating Pressure <strong>and</strong> Temperature Rating based on the elastomers.<br />
Makeup<br />
Length<br />
in. (mm)<br />
22.8<br />
(579)<br />
25.2<br />
(640)<br />
14.4<br />
(365)<br />
2 7/8-in. Gun Pin<br />
2 7/8-in. Gun Pin<br />
End Connections<br />
4-6 Acme Pin x<br />
Modified NC38 Pin<br />
2 7/8-6 Acme <strong>and</strong><br />
Pin x 4-6 Acme Pin x<br />
Modified NC38 Pin<br />
Modified NC38 Box x<br />
4-6 Acme Pin<br />
NC38 Box x<br />
Modified NC38 Pin<br />
Modified NC38 Box x<br />
4-6 Acme Pin x<br />
2 7/8-6 Acme Pin<br />
End Connections<br />
5-in. Gun Pin<br />
5-in. Gun Pin<br />
5-in. Gun Pin<br />
280,500<br />
(127 232)<br />
247,000<br />
(112 354)<br />
Tensile Rating<br />
lb (kg)<br />
493,500<br />
(223,848)<br />
Limited by 4-6 Acme<br />
Pin Thd<br />
493,500<br />
(223,848)<br />
Limited by 4-6 Acme<br />
Pin Thd<br />
493,500<br />
(223,848)<br />
Limited by 4-6 Acme<br />
Pin Thd<br />
398,000<br />
(180,530)<br />
Limited by NC38 Box<br />
493,500<br />
(223,848)<br />
Limited by 4-6 Acme<br />
Pin Thd<br />
Tensile Rating<br />
lb (kg)<br />
540,600<br />
(245 212)<br />
540,600<br />
(245 212)<br />
540,600<br />
(245 212)
Detach Separating Gun Connector<br />
The Detach separating gun connector<br />
allows operators to deploy long gun<br />
sections into the well. The guns are<br />
deployed downhole in a single trip <strong>and</strong><br />
placed across the perforating zone<br />
supported by a gun hanger or plug. The<br />
guns are fired when desired <strong>and</strong> then,<br />
will automatically separate, which<br />
allows them to be retrieved in<br />
manageable sections or left in the hole.<br />
The Detach separating gun connector is<br />
ideal for use in monobore wells with<br />
rathole length restrictions <strong>and</strong> in<br />
rigless completions.<br />
Rathole Length Restriction<br />
In this application, insufficient rathole<br />
length causes the uppermost gun<br />
modules to remain adjacent to the<br />
perforated interval after they are fired<br />
where they may interfere with<br />
production from the well. With the<br />
Detach separating gun connector, gun<br />
sections can be removed from the<br />
perforated interval without having to<br />
kill the well.<br />
Rigless Completion<br />
On wells where the completions are<br />
installed with wireline or coiled tubing,<br />
the Detach separating gun connector or<br />
modular gun system is the preferred<br />
method for perforating. No rig is<br />
required—saving both time <strong>and</strong><br />
money.<br />
SAP No.<br />
101363724<br />
101286871<br />
Upper Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.450)<br />
6P Acme Pin<br />
2 7/8 (73.03)<br />
6P Acme Box × Pin<br />
Operation<br />
When the firing head detonates the<br />
detonating cord initiator, the explosives<br />
train continues through the tool <strong>and</strong><br />
detonates two shaped charges that<br />
punch holes in the vent sub. At this<br />
point, wellbore pressure is allowed to<br />
enter the assembly <strong>and</strong> move the<br />
m<strong>and</strong>rel lock piston upward, allowing<br />
the retaining dogs to move inward,<br />
releasing the stinger, <strong>and</strong> allowing the<br />
gun sections to separate.<br />
Advantages<br />
Can deploy entire gun assembly to<br />
cover the zone of interest in a single<br />
trip <strong>and</strong> retrieve in manageable gun<br />
sections without killing the well<br />
Guns can be retrieved or left at<br />
bottom of the hole<br />
Allows perforating in either<br />
underbalanced or overbalanced<br />
conditions over the entire interval<br />
Detach Separating Gun Connector Specifications<br />
Lower Thread<br />
Size <strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.450)<br />
6P Acme Box<br />
2 7/8 (73.03)<br />
6P Acme Box<br />
Temperature rating is determined by explosive.<br />
*Verification testing<br />
Maximum<br />
OD<br />
in. (mm)<br />
2.75<br />
(69.850)<br />
3.38<br />
(85.85)<br />
Minimum<br />
ID<br />
N/A<br />
N/A<br />
Makeup<br />
Length<br />
ft (m)<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
Detach Separating<br />
Gun Connector<br />
<strong>Perforating</strong> Solutions 5-79<br />
2.86<br />
(0.87)<br />
2.74<br />
(0.83)<br />
1,000<br />
(69)<br />
1,000<br />
(69)<br />
HAL12070<br />
Tensile<br />
Rating<br />
lb (kg)<br />
80,000<br />
(36 300)*<br />
110,000<br />
(49 800)<br />
HAL11525<br />
Burst<br />
Pressure<br />
N/A<br />
N/A<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)
EZ Pass Gun Hanger<br />
The EZ Pass gun hanger is designed<br />
to be run in conjunction with<br />
<strong>Halliburton</strong>’s Modular Gun System.<br />
This advanced design includes slips that<br />
stay retracted within the slip housing<br />
until the tool is set. After the<br />
perforating event, the slips will return<br />
to the running position <strong>and</strong> the tool<br />
auto releases.<br />
If desired, the hanger can be fished with<br />
a st<strong>and</strong>ard pulling tool <strong>and</strong> retrieved<br />
from the well.<br />
Features<br />
Running <strong>and</strong> setting procedures are<br />
similar to common bridge plugs <strong>and</strong><br />
sump packers—uses st<strong>and</strong>ard setting<br />
equipment<br />
Can be set in larger ID after running<br />
through restrictions<br />
Retrievable <strong>and</strong> redressable<br />
May be configured to auto-release or<br />
stay set after gun detonation<br />
Can be deployed on wireline, tubing,<br />
or coiled tubing<br />
One size sets in multiple casing<br />
ranges<br />
Operation<br />
The EZ Pass gun hanger can be run<br />
independently or attached to the gun<br />
system.<br />
If the gun hanger is run attached to the<br />
perforating assembly, it must be<br />
actuated using pressure. The assembly<br />
would be run in, positioned, <strong>and</strong> then<br />
pressure would be applied to the<br />
wellbore to set the tool. No explosive<br />
components would be necessary for<br />
this operation.<br />
If the gun hanger is deployed <strong>and</strong><br />
positioned similar to a wireline-set<br />
permanent or sump packer, the same<br />
power charge-type setting tools are<br />
used to set the hanger. After the setting<br />
tool is removed from the wellbore, the<br />
guns may be deployed as individual<br />
modules or as a complete assembly <strong>and</strong><br />
are stacked on top of the hanger.<br />
A releasing tool is needed to release the<br />
hanger <strong>and</strong> may be run on the bottom<br />
of the perforating assembly. When<br />
activated, the releasing tool fires a<br />
shaped charge <strong>and</strong> breaches the top of<br />
the hanger. This process allows the gun<br />
weight to be transferred to the inner<br />
m<strong>and</strong>rel, placing the hanger in the<br />
releasing position <strong>and</strong> forcing the slips<br />
away from the casing.<br />
The EZ Pass gun hanger is designed<br />
with a 2.75 fishing neck <strong>and</strong> can be<br />
fished with a st<strong>and</strong>ard pulling tool. The<br />
slips will retract into the ID of the tool<br />
<strong>and</strong> helps allow it to be retrieved<br />
through a wellbore restriction.<br />
EZ Pass Gun Hanger<br />
5-80 <strong>Perforating</strong> Solutions<br />
HAL12794
Casing Size<br />
<strong>and</strong><br />
SAP No.<br />
4 1/2<br />
101320360<br />
5 1/2<br />
101315538<br />
7<br />
101321131<br />
Casing<br />
Weights*<br />
lb<br />
9.5 - 15.1<br />
20 / 23 / 26<br />
29 / 32 / 35<br />
Range of<br />
Casing IDs*<br />
in. (cm)<br />
4.09 - 3.826<br />
(10.4 - 9.72)<br />
4.778 - 4.548<br />
(12.14 - 11.55)<br />
6.184 - 6.004<br />
(15.70 - 15.25)<br />
Tool<br />
Maximum<br />
OD<br />
(With Slips<br />
Retracted)<br />
in. (cm)<br />
3.50<br />
(8.89)<br />
4.125<br />
(10.5)<br />
5.375<br />
(13.65)<br />
EZ Pass Gun Hanger Specifications<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
18,000**<br />
(1241)<br />
20,000**<br />
(1450)<br />
20,000**<br />
(1450)<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
500<br />
(34.5)<br />
500<br />
(34.5)<br />
500<br />
(34.5)<br />
Temperature<br />
Rating<br />
°F (°C)<br />
400<br />
(204.4)<br />
400<br />
(204.4)<br />
400<br />
(204.4)<br />
Tensile<br />
Rating<br />
lb (kg)<br />
74,000<br />
(33 600)<br />
74,000<br />
(33 600)<br />
74,000<br />
(33 600)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
18,000<br />
(1241)<br />
20,000<br />
(1450)<br />
20,000<br />
(1450)<br />
Overall<br />
Length<br />
(Maximum)<br />
ft (mm)<br />
Maximum<br />
Gun Weight<br />
lb (kg)<br />
<strong>Perforating</strong> Solutions 5-81<br />
5.1<br />
(1.55)<br />
5.1<br />
(1.55)<br />
5.1<br />
(1.55)<br />
30,000<br />
(13 600)<br />
30,000<br />
(13 600)<br />
30,000<br />
(13 600)<br />
*Recommended<br />
**Maximum Operating Pressure based on hydrostatic pressure <strong>and</strong> applied gun weight.<br />
The EZ Pass hanger does not have minimum ID or Burst Pressure requirements.<br />
NOTE: The EZ Pass gun hanger is designed with specific features to enhance its retrievability; however, due to the uncertainty of the wellbore conditions created by the<br />
perforating event, the retrieval of this tool cannot be assured.<br />
Weight<br />
lb (kg)<br />
116<br />
(52.6)<br />
165<br />
(74.8)<br />
180<br />
(81.7)
Automatic-Release Gun Hanger—Rotational Set<br />
For high volume testing <strong>and</strong><br />
production, the automatic-release gun<br />
hanger (ARGH) allows perforating<br />
<strong>and</strong> testing of a zone without<br />
imposing downhole restrictions. The<br />
perforating assembly can be<br />
positioned <strong>and</strong> retained adjacent to<br />
the desired interval. The drillpipe or<br />
tubing is then removed. After all<br />
surface equipment is installed, the<br />
guns are detonated <strong>and</strong> then released<br />
automatically into the bottom of the<br />
well.<br />
Features<br />
With the ARGH:<br />
No tubing is required between the<br />
guns <strong>and</strong> packer<br />
No wireline work is required to drop<br />
the assembly<br />
No restrictions are left in the casing<br />
below the packer<br />
The maximum desired<br />
underbalanced pressure can be used<br />
Production tubing can be run <strong>and</strong><br />
tested independently from other<br />
tools<br />
The ARGH <strong>and</strong> guns are run on the<br />
workstring<br />
The risk of presetting the packer is<br />
reduced<br />
In BigBore monobore completions,<br />
the production tubing <strong>and</strong><br />
permanent packer are installed<br />
before running the ARGH<br />
perforating assembly<br />
Remedial work can be performed<br />
without pulling production<br />
equipment (such as setting bridge<br />
plugs, adding perforations, running<br />
coiled tubing, etc.)<br />
Lower gun-firing pressures can be<br />
used since all production equipment<br />
is pressure-tested before the guns are<br />
installed in the well (no need to<br />
exceed previous test pressures)<br />
Operation<br />
The ARGH is made up on the bottom<br />
of the perforating assembly. A righth<strong>and</strong><br />
release on/off tool is made up on<br />
the top of the bottomhole assembly<br />
(BHA). After the BHA is correlated on<br />
depth, the operator picks up the string,<br />
turns it to the right, <strong>and</strong> slacks off<br />
weight on the ARGH. The ARGH<br />
should be set at this point.<br />
With weight still on the BHA, the<br />
operator continues to turn the<br />
workstring to the right to release the<br />
on/off tool.<br />
As the guns are detonated, the explosive<br />
train is continued to the ARGH. Two<br />
shaped charges are detonated into a<br />
sealed fluid chamber. This action<br />
eliminates the support to the slip<br />
assembly. The ARGH <strong>and</strong> perforating<br />
assembly are then released<br />
automatically <strong>and</strong> fall to the bottom.<br />
Primacord<br />
Shaped<br />
Charges<br />
Silicone<br />
Fluid<br />
Chamber<br />
Slip<br />
Assembly<br />
5-82 <strong>Perforating</strong> Solutions<br />
HAL10516<br />
Auto-Release Gun Hanger<br />
Rotational Set
Casing OD<br />
in. (mm)<br />
3 1/2<br />
(88.9)<br />
4 1/2<br />
(114.3)<br />
5<br />
(127)<br />
5 1/2<br />
(139.7)<br />
7<br />
(177.8)<br />
7 5/8<br />
(193.7)<br />
9 5/8<br />
(244.5)<br />
Casing Range<br />
lb/ft (kg/m)<br />
5.7-10.2<br />
(8.48-15.18)<br />
9.5-13.5<br />
(14.14-20.09)<br />
11.5-18<br />
(17.11-26.78)<br />
13-26<br />
(19.34-38.69)<br />
17-38<br />
(25.3-56.54)<br />
20-39<br />
(29.76-58.03)<br />
29.3-53.5<br />
(43.6-79.61)<br />
Automatic-Release Gun Hanger—Rotational Set Specifications<br />
Maximum OD<br />
in. (mm)<br />
2.75<br />
(69.85)<br />
3.75<br />
(95.25)<br />
3.75<br />
(95.25)<br />
4.5<br />
(114.3)<br />
5.5<br />
(123.2)<br />
5.5<br />
(123.2)<br />
8.0<br />
(203.2)<br />
Length<br />
ft (m)<br />
3.33<br />
(1.02)<br />
4.88<br />
(1.49)<br />
4.88<br />
(1.49)<br />
5.92<br />
(1.80)<br />
6.04<br />
(1.84)<br />
6.04<br />
(1.84)<br />
7.08<br />
(2.16)<br />
Minimum Tensile Rating<br />
lb (kg)<br />
25,000<br />
(11 300)<br />
85,000<br />
(38 500)<br />
85,000<br />
(38 500)<br />
120,000<br />
(54 400)<br />
120,000<br />
(54 400)<br />
120,000<br />
(54 400)<br />
120,000<br />
(54 400)<br />
Minimum BHA Weight<br />
lb (kg)<br />
Maximum Gun Weight<br />
lb (kg)<br />
<strong>Perforating</strong> Solutions 5-83<br />
150<br />
(68)<br />
300<br />
(136)<br />
300<br />
(136)<br />
500<br />
(227)<br />
600<br />
(272)<br />
600<br />
(272)<br />
600<br />
(272)<br />
12,300<br />
(5580)<br />
40,000<br />
(18 140)<br />
40,000<br />
(18 140)<br />
40,000<br />
(18 140)<br />
40,000<br />
(18 140)<br />
40,000<br />
(18 140)<br />
40,000<br />
(18 140)
Automatic-Release Gun Hanger—Automatic-J M<strong>and</strong>rel<br />
For high volume testing <strong>and</strong><br />
production, the automatic-release gun<br />
hanger (ARGH) allows perforating<br />
<strong>and</strong> testing of a zone without<br />
imposing downhole restrictions. The<br />
perforating assembly can be<br />
positioned <strong>and</strong> retained adjacent to<br />
the desired interval. The drillpipe or<br />
tubing is then removed. After all<br />
surface equipment is installed, the<br />
guns are detonated <strong>and</strong> then released<br />
automatically into the bottom of the<br />
well.<br />
Features<br />
With the ARGH:<br />
No tubing is required between the<br />
guns <strong>and</strong> packer<br />
No wireline work is required to drop<br />
the assembly<br />
No restrictions are left in the casing<br />
below the packer<br />
The maximum desired<br />
underbalanced pressure can be used<br />
Production tubing can be run<br />
<strong>and</strong> tested independently from<br />
other tools<br />
The automatic-J ARGH <strong>and</strong> guns are<br />
run on wireline, slickline, coiled<br />
tubing, or the workstring<br />
In BigBore monobore completions,<br />
the production tubing <strong>and</strong><br />
permanent packer are installed<br />
before running the ARGH<br />
perforating assembly<br />
Remedial work can be performed<br />
without pulling production<br />
equipment (such as setting bridge<br />
plugs, adding perforations, running<br />
coiled tubing, etc.)<br />
Lower gun-firing pressures can be<br />
used since all production equipment<br />
is pressure-tested before the guns are<br />
installed in the well (no need to<br />
exceed previous test pressures)<br />
Operation<br />
The automatic-J m<strong>and</strong>rel can be run<br />
on wireline, slickline, coiled tubing, or<br />
the workstring. Rotation is not<br />
required to set the automatic-J gun<br />
hanger. Upward <strong>and</strong> downward<br />
manipulation either sets or un-sets the<br />
hanger. As the guns are detonated, the<br />
explosive train is continued to the<br />
ARGH. Two shaped charges are<br />
detonated into a sealed fluid chamber.<br />
This action eliminates the support to<br />
the slip assembly. The ARGH <strong>and</strong><br />
perforating assembly are then released<br />
automatically <strong>and</strong> fall to the bottom.<br />
Silicone Fluid<br />
Chamber<br />
Slip Cone<br />
Automatic-J<br />
M<strong>and</strong>rel<br />
Primacord<br />
Slip Assembly<br />
Time-Delay Firer<br />
Crossover<br />
5-84 <strong>Perforating</strong> Solutions<br />
HAL10542<br />
Automatic-Release<br />
Gun Hanger (ARGH)<br />
Automatic-J M<strong>and</strong>rel
Casing OD<br />
in. (mm)<br />
2 7/8<br />
(73.1)<br />
3 1/2<br />
(88.9)<br />
4<br />
(101.6)<br />
3 1/2<br />
(88.9)<br />
Slimhole<br />
4 1/2<br />
(114.3)<br />
5<br />
(127)<br />
4 1/2<br />
(114.3)<br />
Slimhole<br />
5 1/2<br />
(139.7)<br />
7<br />
(177.8)<br />
7 5/8<br />
(193.7)<br />
9 5/8<br />
(244.5)<br />
10 3/4<br />
(273.05)<br />
Casing Range<br />
lb/ft (kg/m)<br />
2 7/8<br />
6.4-6.50<br />
(9.52-9.67)<br />
3 1/2<br />
5.75-10.2<br />
(8.56-15.18)<br />
4<br />
14.40<br />
(21.43)<br />
3 1/2<br />
9.2-12.95<br />
(13.69-19.27)<br />
4 1/2<br />
9.5-13.5<br />
(14.14-20.09)<br />
5<br />
15.0-18.0<br />
(22.32-26.78)<br />
4 1/2<br />
15.1-16.9<br />
(22.46-25.15)<br />
5 1/2<br />
15.50-23<br />
(23.06-34.22)<br />
7<br />
20-38<br />
(29.76-56.54)<br />
7 5/8<br />
24-39<br />
(35.71-58.03)<br />
9 5/8<br />
29.3-53.5<br />
(43.6-79.61)<br />
10 3/4<br />
60.7 - 71.10<br />
(90.31 - 105.78)<br />
Maximum<br />
OD<br />
in. (mm)<br />
Automatic-J M<strong>and</strong>rel Specifications<br />
2.25<br />
(57.2)<br />
2.75<br />
(73.0)<br />
2.75<br />
(73.0)<br />
2.50<br />
(63.5)<br />
3.75<br />
(95.25)<br />
3.75<br />
(95.25)<br />
3.50<br />
(88.9)<br />
4.50<br />
(114.3)<br />
5.5<br />
(123.2)<br />
5.5<br />
(123.2)<br />
8.0<br />
(203.2)<br />
9.17<br />
(233)<br />
Length<br />
ft (m)<br />
4.49-4.87<br />
(1.349-1.47)<br />
4.87-5.28<br />
(1.47-1.59)<br />
4.87-5.28<br />
(1.47-1.59)<br />
53.79-58.47<br />
(16.40-17.82)<br />
7.95-9.28<br />
(2.40-2.80)<br />
7.95-9.28<br />
(2.40-2.80)<br />
58.34-67.29<br />
(17.78-20.51)<br />
9.31-10.29<br />
(2.80-3.10)<br />
9.26-10.44<br />
(2.79-3.14)<br />
9.26-10.44<br />
(2.79-3.14)<br />
7.08<br />
(2.16)<br />
9.8<br />
(299)<br />
Maximum Operating<br />
Pressure*<br />
psi (bar)<br />
20,000<br />
(1379)<br />
Tensile Rating<br />
lb (kg)<br />
25,000<br />
(11 300)<br />
Minimum<br />
BHA Weight<br />
lb (kg)<br />
Maximum<br />
Gun Weight<br />
lb (kg)<br />
<strong>Perforating</strong> Solutions 5-85<br />
N/A<br />
N/A<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
N/A<br />
N/A<br />
N/A<br />
N/A<br />
N/A<br />
N/A<br />
25,000<br />
(11 300)<br />
25,000<br />
(11 300)<br />
25,000<br />
(11 340)<br />
85,000<br />
(38 500)<br />
85,000<br />
(38 500)<br />
25,000<br />
(11 340)<br />
120,000<br />
(54 400)<br />
120,000<br />
(54 400)<br />
120,000<br />
(54 400)<br />
120,000<br />
(54 400)<br />
160,300<br />
(72 700)<br />
*As total gun weight increases, the maximum operating pressure decreases.<br />
Temperature rating is determined by explosives.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
150<br />
(68)<br />
150<br />
(68)<br />
150<br />
(68)<br />
150<br />
(68)<br />
300<br />
(136)<br />
300<br />
(136)<br />
200<br />
(91)<br />
500<br />
(227)<br />
600<br />
(272)<br />
600<br />
(272)<br />
600<br />
(272)<br />
600<br />
(272)<br />
9,000<br />
(4050)<br />
12,300<br />
(5580)<br />
12,300<br />
(5580)<br />
20,000<br />
(9072)<br />
40,000<br />
(18 140)<br />
40,000<br />
(18 140)<br />
20,000<br />
(9072)<br />
40,000<br />
(18 140)<br />
40,000<br />
(18 140)<br />
40,000<br />
(18 140)<br />
40,000<br />
(18 140)<br />
250,000<br />
(113 400)
Explosive Transfer Swivel Sub<br />
The explosive transfer swivel sub allows two sections of guns<br />
to rotate independently of one another. This independent<br />
rotation is important on long strings of guns in horizontal<br />
wells when they must be oriented in a specific direction. It is<br />
easier to orient several short sections of guns, rather than one<br />
long section.<br />
Features<br />
Useful in horizontal wells when shots need to be oriented<br />
in a specific direction to the wellbore<br />
Bi-directional, allowing firing from either direction<br />
Operation<br />
This swivel sub can be run as a connector between two guns<br />
to allow them to rotate independently without breaking the<br />
explosive train. In other words, this sub passes on the<br />
explosive transfer to the next gun.<br />
SAP No.<br />
101271529<br />
101271553<br />
101271546<br />
101284187<br />
101278821<br />
Thread Size <strong>and</strong><br />
Type<br />
in. (mm)<br />
2 3/8 (60.33)<br />
6P Acme Box × Pin<br />
2 7/8 (73.03)<br />
6P Acme Box × Pin<br />
4.00 (101.60)<br />
6P Acme Box × Pin<br />
4.420 (112.27)<br />
6P Acme Box × Pin<br />
5 1/8 (130.18)<br />
6P Acme Box × Pin<br />
Explosive Transfer Swivel Sub Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
2.75<br />
(69.85)<br />
3.375<br />
(85.73)<br />
4.625<br />
(117.47)<br />
5.125<br />
(130.18)<br />
5.750<br />
(146.05)<br />
Makeup<br />
Length<br />
ft (m)<br />
1.13<br />
(0.344)<br />
1.13<br />
(0.344)<br />
1.16<br />
(0.353)<br />
1.13<br />
(0.344)<br />
1.16<br />
(0.353)<br />
Maximum Operating<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
20,000<br />
(1379)<br />
Explosive Transfer<br />
Swivel Sub Assembly<br />
5-86 <strong>Perforating</strong> Solutions<br />
HAL10513<br />
Tensile Strength<br />
lb (kg)<br />
108,000<br />
(48 988)<br />
190,000<br />
(86 183)<br />
332,000<br />
(150 593)<br />
416,000<br />
(188 694)<br />
410,000<br />
(185 973)<br />
Maximum Operating<br />
Tensile Load*<br />
lb (kg)<br />
32,000<br />
(14 515)<br />
40,000<br />
(18 144)<br />
60,000<br />
(27 216)<br />
60,000<br />
(27 216)<br />
60,000<br />
(27 216)<br />
*Maximum operating tensile load is the point at which the ball bearing race will start to deform, <strong>and</strong> the tool will not function as designed.<br />
Temperature rating is determined by explosive.
Shearable Safety Sub<br />
The shearable safety sub is designed to<br />
provide a gap in the explosive train,<br />
which could be severed at surface with<br />
the shear rams. The most common<br />
application is in the use of live<br />
well intervention.<br />
The shearable safety sub provides two<br />
levels of defense against wellbore<br />
pressures. First, it provides a sub with a<br />
smooth profile that is utilized by<br />
closing the sealing rams to control<br />
pressure when the gun connection is<br />
made up or broken out. Secondly, if the<br />
well conditions become dangerous <strong>and</strong><br />
the shear rams need to be activated, it<br />
provides an area in the gun assembly<br />
that does not contain explosives <strong>and</strong><br />
can be safely severed by the shear rams.<br />
Features<br />
Continues the explosive train<br />
without use of continuous explosives<br />
Isolates pressure from below<br />
Allows a smooth sealing area for the<br />
pipe rams to seal against<br />
SAP No.<br />
101245799<br />
Thread Size <strong>and</strong><br />
Type<br />
2 7/8-in. Acme<br />
Box x Pin<br />
Maximum OD<br />
in. (mm)<br />
3.375<br />
(85.73)<br />
Temperature rating is determined by explosive.<br />
Uses st<strong>and</strong>ard explosives<br />
Contains st<strong>and</strong>ard 3 3/8-in. gun<br />
connections above <strong>and</strong> below<br />
Can be run with tubing, coiled<br />
tubing, wireline, <strong>and</strong> modular<br />
applications<br />
Can be sheared independently of the<br />
guns firing<br />
Can be redressed at minimal cost<br />
This tool has been successfully sheared<br />
during testing using the following:<br />
Shaffer shear 7 1/16-in. 10k safety<br />
head<br />
Piston diameter of 14 in. (153 in.²)<br />
Sheared at 2,000 psi<br />
Force required to shear tool =<br />
(153 in.²) (2,000 psi) = 306,000 lb<br />
Shearable Safety Sub Specifications<br />
Minimum ID<br />
N/A<br />
Makeup<br />
Length<br />
ft (m)<br />
2.50<br />
(0.76)<br />
Maximum Operating<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
Minimum Operating<br />
Pressure<br />
psi (bar)<br />
Shearable Safety Sub<br />
<strong>Perforating</strong> Solutions 5-87<br />
N/A<br />
HAL15454<br />
Tensile<br />
Strength<br />
lb (kg)<br />
200,000<br />
(90 700)<br />
Weight<br />
lb (kg)<br />
54.4<br />
(24.6)
Roller T<strong>and</strong>em Assembly<br />
Roller t<strong>and</strong>em assemblies are used to reduce the friction<br />
between the perforating guns <strong>and</strong> the casing. In some cases,<br />
the frictional drag can be reduced by as much as 90%.<br />
Applications<br />
Running guns on coiled tubing in horizontal <strong>and</strong> highly<br />
deviated wells<br />
Dropping the guns into the rathole in highly deviated wells<br />
Can be deployed in conjunction with the modular gun<br />
system<br />
SAP No.<br />
120021632<br />
100155770<br />
100155771<br />
101313551<br />
Size<br />
in. (mm)<br />
2 3/4<br />
(69.85)<br />
3 3/8<br />
(85.72)<br />
4 5/8<br />
(117.47)<br />
7<br />
(177.80)<br />
Roller T<strong>and</strong>em Assembly<br />
5-88 <strong>Perforating</strong> Solutions<br />
HAL10567<br />
Roller T<strong>and</strong>em Assembly Specifications<br />
Effective OD<br />
in. (mm)<br />
3.06<br />
(77.72)<br />
3.76<br />
(95.50)<br />
5.63<br />
(143.00)<br />
8.20<br />
(208.28)<br />
No. of Rollers<br />
6<br />
(2 rows of 3)<br />
8<br />
(2 rows of 4)<br />
8<br />
(2 rows of 4)<br />
8<br />
(2 rows of 4)<br />
Roller<br />
Phasing<br />
60°<br />
45°<br />
45°<br />
45°<br />
Tensile Strength<br />
lb (kg)<br />
140,000<br />
(63 503)<br />
246,000<br />
(111 584)<br />
414,000<br />
(187 787)<br />
444,000<br />
(201 395)<br />
Makeup Length<br />
in. (mm)<br />
6.97<br />
(177.04)<br />
7.70<br />
(195.58)<br />
9.25<br />
(234.95)<br />
15.52<br />
(394.21)
Centralizer T<strong>and</strong>em<br />
In certain types of TCP operations, it is desirable to<br />
centralize the guns <strong>and</strong> other tools in the casing. <strong>Halliburton</strong><br />
has designed a full range of centralizers to meet this<br />
requirement for all gun sizes. The centralizers are designed to<br />
minimize the possibility of “hanging up” while running or<br />
pulling the guns <strong>and</strong> to maximize the flow area around the<br />
centralizers.<br />
Application<br />
Two of the primary applications for the centralizers are:<br />
1. When perforating with big hole charges, it is<br />
recommended to centralize the guns to ensure that the<br />
exit holes in the casing will all be of a consistent size. If<br />
the guns are not centralized, the size of the exit holes<br />
will vary according to the clearance from the gun to<br />
the casing. This can cause problems with s<strong>and</strong> control<br />
operations.<br />
2. In modular gun completions, it is necessary to<br />
centralize the gun modules to obtain a reliable<br />
explosive transfer between modules.<br />
Contact your <strong>Halliburton</strong> representative for a list of available<br />
centralizers.<br />
Centralizer<br />
<strong>Perforating</strong> Solutions 5-89<br />
Guns<br />
Centralizer<br />
HAL15986<br />
Centralizer T<strong>and</strong>em
Emergency Release Assembly<br />
The emergency release assembly was designed to run in<br />
conjunction with the automatic-release gun hanger<br />
assembly. When deploying the gun hanger on tubing or drill<br />
pipe, the emergency release is run between the gun hanger<br />
<strong>and</strong> guns to serve as a weak point in case the hanger gets<br />
stuck while running in the hole. Pulling or jarring on the<br />
pipe will cause the emergency release assembly to shear,<br />
allowing the retrieval of the guns <strong>and</strong> tubing from the well.<br />
When deploying the gun hanger on wireline, the rope socket<br />
typically acts as the weak point.<br />
SAP No.<br />
101201127<br />
Emergency Release Assembly Specifications<br />
OD Size<br />
in. (mm)<br />
3 3/8<br />
(85.73)<br />
Emergency Release Assembly<br />
5-90 <strong>Perforating</strong> Solutions<br />
HAL15987<br />
No. Shear Screws Temperature Rating<br />
8 steel shear screws rated at<br />
5,600 lb per screw<br />
Determined by explosives<br />
Pressure Rating<br />
psi (bar)<br />
25,000<br />
(1724)
Annular Pressure-Control Line Vent<br />
The annular pressure-control line (APF-C) vent is a device<br />
that isolates the tubing from annulus fluid or pressure. The<br />
vent is actuated by rathole pressure after the perforating<br />
assembly has been detonated. It then provides a flowpath for<br />
the formation fluid into the tubing string.<br />
Features<br />
Ideal for highly deviated or horizontal wells<br />
Requires minimal pressure to operate<br />
Eliminates nitrogen displacement or swabbing the tubing<br />
string to achieve desired underbalance<br />
Operation<br />
The APF-C vent is run directly on top of the APF-C firing<br />
head. When the perforating assembly is detonated, gun<br />
pressure shifts an actuating piston into a power piston. This<br />
shift opens the flow ports to the tubing.<br />
SAP No.<br />
120038049<br />
101016565<br />
Thread Size <strong>and</strong><br />
Type<br />
in. (mm)<br />
2 3/8 (60.33) EUE<br />
8 Rd Box ×<br />
2 7/8 (73.03) 6P<br />
Acme Box<br />
2 7/8 (73.03)<br />
EUE 8 Rd Box ×<br />
2 7/8 (73.03) 6P<br />
Acme Box<br />
Annular Pressure-Control Line<br />
(APF-C) Vent<br />
Annular Pressure-Control Line (APF-C) Vent Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
3.38<br />
(85.85)<br />
3.88<br />
(98.55)<br />
Minimum<br />
ID<br />
in. (mm)<br />
Nonfull-bore<br />
Nonfull-bore<br />
No. <strong>and</strong> ID<br />
of Ports<br />
in. (mm)<br />
4@1.0<br />
(25.4)<br />
5@1.0<br />
(25.4)<br />
Flow<br />
Area<br />
in. 2 (cm 2 )<br />
2.63<br />
(16.97)<br />
3.93<br />
(25.34)<br />
Makeup<br />
Length<br />
ft (m)<br />
<strong>Perforating</strong> Solutions 5-91<br />
2.37<br />
(0.72)<br />
2.43<br />
(0.74)<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
HAL15441<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
150,000<br />
(68 000)<br />
170,000<br />
(77 000)<br />
Burst<br />
Pressure<br />
psi (bar)<br />
22,000<br />
(1515)<br />
15,000<br />
(1035)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
22,000<br />
(1515)<br />
15,000<br />
(1035)
Annular Pressure-Control Line Swivel Sub<br />
When run in conjunction with the annular pressure-control<br />
line (APF-C) firing head, the APF-C swivel sub provides a<br />
swivel point between the guns <strong>and</strong> packer when it is desired<br />
to have the guns rotate freely as when orienting shots in a<br />
deviated well.<br />
Features<br />
Compatible with APF-C firing head <strong>and</strong> control line<br />
Can be run anywhere between the packer <strong>and</strong> the<br />
firing head<br />
Transmits pressure through the control line while rotating<br />
Operation<br />
The APF-C swivel is made up in the string between the<br />
packer <strong>and</strong> the firing head. A section of control line is made<br />
up from the packer to the top of the swivel. A second section<br />
of control line is made up from the bottom of the swivel to<br />
the APF-C firing head. Annulus pressure is transmitted from<br />
the packer, through the swivel to the firing head.<br />
SAP No.<br />
101230619<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 7/8 EU 8rd<br />
Box × Pin<br />
APF-C Swivel Sub<br />
Annular Pressure-Control Line (APF-C) Swivel Sub Specifications<br />
Maximum OD<br />
in. (mm)<br />
5.13<br />
(130.30)<br />
Minimum ID<br />
in. (mm)<br />
2.0<br />
(50.8)<br />
*The APF-C swivel sub is not designed to operate with differential pressure.<br />
Tensile Strength<br />
lb (kg)<br />
200,000<br />
(90 718)<br />
Operating Load<br />
Limit Rating<br />
lb (kg)<br />
36,000<br />
(16 329)<br />
5-92 <strong>Perforating</strong> Solutions<br />
HAL10539<br />
Burst<br />
Pressure<br />
psi (bar)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
NA* NA*<br />
Makeup<br />
Length<br />
ft (m)<br />
1.3<br />
(0.39)
Annular Pressure-Control Line Tubing Release<br />
The 2 7/8-in. annular pressure-control line tubing release<br />
assembly (APF-C TR) provides a mechanical method of<br />
releasing the APF-C firing head <strong>and</strong> VannGun® assembly<br />
from the tubing string.<br />
Features<br />
Releasing the gun assembly opens the tubing for other<br />
tools such as production logging, testing, <strong>and</strong> treating<br />
Low cost method to release gun assembly<br />
Utilizes off-the-shelf shifting tools<br />
No time limit on dropping the gun assembly<br />
Leaves perforations uncovered <strong>and</strong> helps eliminate<br />
flow restriction<br />
Operation<br />
The APF-C TR is run between the APF-C firing head <strong>and</strong> the<br />
7- or 9 5/8-in. annulus pressure transfer reservoir (APTR).<br />
The control line for the APF-C is attached to the control line<br />
housing, which transfers the pressure through the APF-C TR<br />
<strong>and</strong> out the finger sub to a second control line. The second<br />
control line transfers the pressure down to the APF-C firing<br />
head. Releasing can be accomplished by the use of a st<strong>and</strong>ard<br />
<strong>Halliburton</strong> or Garret shifting tool.<br />
SAP No.<br />
87921<br />
APF-C Tubing Release (APF-C TR)<br />
Annular Pressure Control Line Tubing Release (APF-C TR) Specifications<br />
Upper Thread Size<br />
<strong>and</strong> Type<br />
2 7/8 (73.03)<br />
EUE 8 Rd Box<br />
Lower Thread Size<br />
<strong>and</strong> Type<br />
2 7/8 (73.03)<br />
EUE 8 Rd Pin<br />
Makeup<br />
Length<br />
ft (m)<br />
2.24<br />
(0.68)<br />
Maximum OD<br />
in. (mm)<br />
4.62<br />
(117.35)<br />
Minimum ID<br />
in. (mm)<br />
<strong>Perforating</strong> Solutions 5-93<br />
HAL10589<br />
Latch Sizes – 1.88<br />
(47.75), 2.125 (53.98),<br />
or 2.25 (57.15)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
120,000<br />
(54 431)<br />
Burst<br />
Pressure<br />
psi (bar)<br />
12,000<br />
(827)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
11,000<br />
(758)
Bar Pressure Vent<br />
The bar pressure vent (BPV) is<br />
designed to achieve a differential<br />
pressure between the formation <strong>and</strong><br />
tubing string. This tool helps to safely<br />
allow a differential pressure in wells<br />
with existing open perforations or in<br />
unperforated wells. The BPV is an<br />
internal sliding-sleeve tool actuated by<br />
pressure in the tubing. It is run between<br />
the packer <strong>and</strong> the guns.<br />
Features<br />
Offers an inexpensive way to create<br />
the necessary underbalance<br />
Allows the hole to be totally<br />
contained at the wellhead before<br />
the surge<br />
Allows the sleeve to lock in place<br />
once the port is opened<br />
Can be run with any packer<br />
Does not rely on tubing<br />
manipulation (Hydrostatic<br />
pressure in the tubing is the only<br />
force required)<br />
SAP No.<br />
101201951<br />
100155788<br />
100010328<br />
100155789<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.33)<br />
EUE 8 Rd<br />
Box × Pin<br />
2 3/8 (60.33)<br />
EUE 8 Rd<br />
Box × Pin<br />
2 7/8 (73.03)<br />
EUE 8 Rd<br />
Box × Pin<br />
3 1/2 (88.90)<br />
EUE 8 Rd<br />
Box × Pin<br />
Maximum<br />
OD<br />
in. (mm)<br />
3.06<br />
(77.72)<br />
3.63<br />
(92.20)<br />
3.88<br />
(98.55)<br />
5.0<br />
(127.0)<br />
Minimum<br />
ID<br />
in. (mm)<br />
1.50<br />
(38.10)<br />
1.90<br />
(48.26)<br />
2.25<br />
(57.15)<br />
2.75<br />
(69.85)<br />
Operation<br />
The BPV consists of a ported housing<br />
<strong>and</strong> a sliding sleeve. The sliding sleeve is<br />
isolated from the tubing pressure by a<br />
break plug with a hollow center.<br />
The BPV is activated when the<br />
detonating bar is dropped through the<br />
tubing <strong>and</strong> shears the hollow break<br />
plug. This action allows the pressure<br />
in the tubing to force the sleeve<br />
upward, uncovering the ports. A lock<br />
ring locks the sleeve open. The<br />
detonating bar continues downward<br />
to strike the firing head.<br />
If the vent must be opened before<br />
dropping the detonating bar, dropping<br />
a special tube will open the vent <strong>and</strong><br />
not fire the guns. When the bar is<br />
dropped, it will pass through the tube<br />
<strong>and</strong> fire the guns.<br />
Bar Pressure Vent (BPV) Specifications<br />
No. <strong>and</strong> ID<br />
of Ports<br />
in. (mm)<br />
4 @ 1.0<br />
(25.40)<br />
4 @ 1.0<br />
(25.40)<br />
4 @ 1.13<br />
(28.70)<br />
4 @ 1.75<br />
(44.45)<br />
Flow<br />
Area<br />
in. 2 (cm 2 )<br />
1.77<br />
(11.40)<br />
3.14<br />
(20.27)<br />
3.98<br />
(25.65)<br />
5.94<br />
(38.32)<br />
Makeup<br />
Length<br />
ft (m)<br />
1.30<br />
(0.40)<br />
1.30<br />
(0.40)<br />
1.40<br />
(0.43)<br />
1.57<br />
(0.48)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
15,000<br />
(1035)<br />
15,000<br />
(1035)<br />
15,000<br />
(1035)<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
Maximum<br />
Differential<br />
Pressure<br />
psi (bar)<br />
Bar Pressure Vent (BPV)<br />
5-94 <strong>Perforating</strong> Solutions<br />
1,000<br />
(69)<br />
1,000<br />
(69)<br />
1,000<br />
(69)<br />
1,000<br />
(69)<br />
8,000<br />
(550)<br />
8,000<br />
(550)<br />
8,000<br />
(550)<br />
8,000<br />
(550)<br />
HAL10565<br />
Tensile<br />
Strength<br />
lb (kg)<br />
140,000<br />
(63 400)<br />
146,000<br />
(66 200)<br />
160,000<br />
(72 500)<br />
400,000<br />
(181 400)<br />
Burst<br />
Pressure<br />
psi (bar)<br />
24,000<br />
(1655)<br />
18,000<br />
(1240)<br />
19,000<br />
(1310)<br />
22,000<br />
(1515)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
22,000<br />
(1515)<br />
17,000<br />
(1170)<br />
18,000<br />
(1240)
Below-Packer Vent Device<br />
The below-packer vent device (BPVD) was developed for<br />
use with the annulus-pressure crossover assembly (APCA).<br />
Surface pressure applied to the annulus is transmitted<br />
through the APCA to a closed chamber below the BPVD<br />
<strong>and</strong> above a pressure-responsive firing head. The BPVD<br />
can be set to work before or after the perforating assembly<br />
is detonated.<br />
Features<br />
Does not require tubing hydrostatic pressure to operate<br />
Can operate in highly deviated wells<br />
Can be used in wells with low formation pressure<br />
Eliminates nitrogen requirements<br />
Helps allow maximum underbalance<br />
Is compatible with several types of firing heads<br />
Can provide reliable <strong>and</strong> accurate pressure response<br />
Operation<br />
To open the BPVD, a predetermined annulus pressure is<br />
transmitted through the APCA to below the BPVD. This<br />
pressure then ruptures a disk in the lower housing of the<br />
BPVD. An actuating piston then forces the venting sleeve<br />
away from the production ports. This action establishes<br />
communication with the tubing string.<br />
SAP No.<br />
100155787<br />
100014176<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.33)<br />
EUE 8 Rd<br />
Box × Pin<br />
2 7/8 (73.03)<br />
EUE 8 Rd<br />
Box × Pin<br />
Maximum OD<br />
in. (mm)<br />
3.38<br />
(85.85)<br />
3.88<br />
(98.55)<br />
Below-Packer Vent<br />
Below-Packer Vent Device (BPVD) Specifications<br />
Minimum ID<br />
in. (mm)<br />
Nonfull-bore<br />
Non-<br />
full-bore<br />
Makeup<br />
Length<br />
ft (m)<br />
2.32<br />
(0.71)<br />
2.26<br />
(0.69)<br />
No. <strong>and</strong> ID<br />
of Ports<br />
in. (mm)<br />
4 @ 1.0<br />
(25.4)<br />
5 @ 1.0<br />
(25.4)<br />
<strong>Perforating</strong> Solutions 5-95<br />
HAL15450<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
15,000<br />
(1035)<br />
15,000<br />
(1035)<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
1,000<br />
(69)<br />
1,000<br />
(69)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
150,000<br />
(68 000)<br />
170,000<br />
(77 000)<br />
HAL15451<br />
Below-Packer Vent<br />
Device (BPVD)<br />
Burst<br />
Pressure<br />
psi (bar)<br />
25,000<br />
(1725)<br />
25,000<br />
(1725)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
22,000<br />
(1515)<br />
25,000<br />
(1725)
Maximum Differential Bar Vent<br />
The maximum differential bar vent<br />
(MDBV) assembly is run between the<br />
perforating guns <strong>and</strong> the packer. After<br />
the packer is set, the opening of the<br />
vent creates communication between<br />
the tubing <strong>and</strong> the rathole. The vent is<br />
opened by breaking the plug inside the<br />
tool <strong>and</strong> allowing the sleeve to<br />
uncover the ports. Running the<br />
MDBV allows the operator to run the<br />
tubing in the well with no hydrostatic<br />
pressure in the tubing.<br />
Features<br />
Operates with a minimum amount<br />
of fluid in the tubing<br />
Helps allow maximum differential<br />
pressure when perforating in lowpressure<br />
formations<br />
Does not depend on tubing<br />
hydrostatic pressure to operate<br />
Assisted mechanically by an<br />
operating spring to help ensure full<br />
<strong>and</strong> complete opening<br />
Can be used in wells with open<br />
perforations to achieve an<br />
underbalance when guns are fired to<br />
add new perforations<br />
SAP No.<br />
100005291<br />
100005294<br />
100156853<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.33)<br />
EUE 8 Rd<br />
Box × Pin<br />
2 7/8 (73.03)<br />
EUE 8 Rd<br />
Box × Pin<br />
3 1/2 (88.9)<br />
EUE 8 Rd<br />
Box × Pin<br />
Operation<br />
The maximum differential bar vent is<br />
held closed by a chamber of silicone<br />
fluid, which keeps a spring compressed.<br />
When the silicone fluid is released from<br />
the chamber, the spring extends <strong>and</strong><br />
opens the vent. Once the break plug is<br />
broken, the silicone fluid drains into<br />
the tubing.<br />
The MDBV will open with up to<br />
1,000 psi (68.95 bar) in the tubing<br />
regardless of rathole pressure. If there is<br />
more than 1,000 psi (68.95 bar) in the<br />
tubing, <strong>and</strong> there is uncertainty about<br />
the rathole pressure, consider the bar<br />
pressure vent instead of the MDBV.<br />
If the vent must be opened before<br />
dropping the detonating bar, dropping<br />
a special tube will open the vent <strong>and</strong><br />
not fire the guns. When the bar is<br />
dropped, it will pass through the tube<br />
<strong>and</strong> fire the guns.<br />
Maximum Differential Bar Vent (MDBV) Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
3.36<br />
(92.20)<br />
3.88<br />
(98.55)<br />
4.50<br />
(114.30)<br />
Minimum<br />
ID<br />
in. (mm)<br />
2.0<br />
(50.80)<br />
2.2<br />
(57.15)<br />
2.7<br />
(69.85)<br />
No. <strong>and</strong> ID<br />
of Ports<br />
in. (mm)<br />
5 @ 1.0<br />
(25.40)<br />
4 @ 1.13<br />
(28.70)<br />
4 @ 1.75<br />
(44.45)<br />
Flow Area<br />
of Ports<br />
in. 2 (cm 2 )<br />
3.92<br />
(25.29)<br />
4.01<br />
(27.87)<br />
9.58<br />
(61.81)<br />
Makeup<br />
Length<br />
ft (m)<br />
Temperature<br />
Rating<br />
(Limited by<br />
Silicone Fluid)<br />
°F (°C)<br />
Maximum Differential Bar Vent<br />
5-96 <strong>Perforating</strong> Solutions<br />
2.29<br />
(0.70)<br />
2.39<br />
(0.73)<br />
2.75<br />
(0.84)<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
350<br />
(176)<br />
350<br />
(176)<br />
350<br />
(176)<br />
HAL15445<br />
Tensile<br />
Strength<br />
lb (kg)<br />
221,000<br />
(100 200)<br />
231,000<br />
(104 700)<br />
245,000<br />
(111 000)<br />
Burst<br />
Pressure<br />
psi (bar)<br />
19,500<br />
(1345)<br />
19,000<br />
(1310)<br />
14,000<br />
(965)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
16,500<br />
(1135)<br />
13,000<br />
(895)<br />
14,000<br />
(965)
Pressure-Operated Vent<br />
The pressure-operated vent (POV) is<br />
designed to achieve a differential<br />
pressure between the formation <strong>and</strong><br />
tubing string <strong>and</strong> to provide a way to<br />
open the vent <strong>and</strong> test the packer before<br />
the guns are fired.<br />
When the guns have been positioned<br />
<strong>and</strong> the packer has been set, the<br />
predetermined amount of fluid is<br />
added to the tubing. Adding the fluid<br />
into the tubing causes the POV to open<br />
<strong>and</strong> creates the proper pressure<br />
differential before firing. Nitrogen may<br />
also be used with or in place of the<br />
fluids to obtain the necessary<br />
hydrostatic pressure in the tubing.<br />
Features<br />
Allows the vent to be opened without<br />
the guns being fired<br />
Allows the packer to be tested before<br />
the guns are fired<br />
Fills tubing automatically when run<br />
with Vann circulating valve<br />
SAP No.<br />
101297298<br />
100014177<br />
100014178<br />
100014179<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.33)<br />
EUE 8 Rd<br />
Box × Pin<br />
2 3/8 (60.33)<br />
EUE 8 Rd<br />
Box × Pin<br />
2 7/8 (73.03)<br />
EUE 8 Rd<br />
Box × Pin<br />
3 1/2 (88.90)<br />
EUE 8 Rd<br />
Box × Pin<br />
Maximum<br />
OD<br />
in. (mm)<br />
3.06<br />
(77.72)<br />
3.63<br />
(92.20)<br />
3.88<br />
(98.55)<br />
5.0<br />
(127.0)<br />
Minimum<br />
ID<br />
in. (mm)<br />
1.50<br />
(38.10)<br />
1.90<br />
(48.26)<br />
2.25<br />
(57.15)<br />
2.75<br />
(69.85)<br />
Can be run with mechanical or<br />
pressure-actuated firing heads<br />
Useful in highly deviated wells<br />
Compatible with other packers<br />
Operation<br />
The POV consists of a ported housing,<br />
a sliding sleeve, <strong>and</strong> a set of shear pins.<br />
The sleeve is held in the closed<br />
position by a variable number of shear<br />
pins. The pins are isolated from<br />
annular pressure <strong>and</strong> are only exposed<br />
to the tubing hydrostatic. The POV<br />
will open when the proper amount of<br />
hydrostatic pressure is applied to the<br />
shear pins. The amount of hydrostatic<br />
it takes to open the POV depends on<br />
how many shear pins are installed in<br />
the tool. When the pins shear, the<br />
hydrostatic pressure forces the sleeve<br />
upward, which uncovers the flow<br />
ports. The sleeve is then locked into<br />
the open position.<br />
Pressure-Operated Vent (POV) Specifications<br />
No. <strong>and</strong> ID<br />
of Ports<br />
in. (mm)<br />
4 @ 1.0<br />
(25.40)<br />
4 @ 1.0<br />
(25.40)<br />
4 @ 1.13<br />
(28.70)<br />
4 @ 1.75<br />
(44.45)<br />
Total<br />
Flow Area<br />
in. 2 (cm 2 )<br />
1.77<br />
(11.40)<br />
3.14<br />
(20.27)<br />
3.98<br />
(25.65)<br />
5.94<br />
(38.32)<br />
Makeup<br />
Length<br />
ft (m)<br />
1.30<br />
(0.40)<br />
1.30<br />
(0.40)<br />
1.40<br />
(0.43)<br />
1.57<br />
(0.48)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
15,000<br />
(1035)<br />
15,000<br />
(1035)<br />
15,000<br />
(1035)<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
Pressure-Operated Vent (POV)<br />
<strong>Perforating</strong> Solutions 5-97<br />
1,000<br />
(69)<br />
1,000<br />
(69)<br />
1,000<br />
(69)<br />
1,000<br />
(69)<br />
HAL10538<br />
Maximum<br />
Differential<br />
Pressure<br />
psi (bar)<br />
8,000<br />
(550)<br />
8,000<br />
(550)<br />
8,000<br />
(550)<br />
8,000<br />
(550)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
140,000<br />
(63 400)<br />
146,000<br />
(66 200)<br />
160,000<br />
(72 500)<br />
400,000<br />
(181 400)<br />
Burst<br />
Pressure<br />
psi (bar)<br />
24,000<br />
(1655)<br />
18,000<br />
(1240)<br />
19,000<br />
(1310)<br />
22,000<br />
(1515)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1380)<br />
22,000<br />
(1515)<br />
17,000<br />
(1170)<br />
18,000<br />
(1240)
Vann Circulating Valve<br />
The Vann circulating valve (VCV) is<br />
designed to be used as a fill-up valve or<br />
as a circulating valve for displacing well<br />
fluids before setting a packer. After the<br />
fluid is displaced, the operator applies<br />
pressure to the tubing or annulus to<br />
rupture a disk <strong>and</strong> close the VCV.<br />
Features<br />
Can be used as a circulating <strong>and</strong><br />
shutoff valve<br />
Often run with other venting or<br />
production devices<br />
Economical <strong>and</strong> reusable<br />
Operation<br />
The VCV consists of a ported housing,<br />
a sliding sleeve, <strong>and</strong> a rupture disk,<br />
which must be ordered separately. The<br />
sliding sleeve, which has two air<br />
chambers, is open while the tool is run<br />
in the hole.<br />
SAP No.<br />
101015372<br />
120038456<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.33)<br />
EUE 8 Rd<br />
Box × Pin<br />
2 7/8 (73.03)<br />
EUE 8 Rd<br />
Box × Pin*<br />
Maximum<br />
OD<br />
in. (mm)<br />
3.38<br />
(85.85)<br />
4.65<br />
(188.11)<br />
The rupture disk is available for<br />
different pressure ratings as needed.<br />
The amount of hydrostatic pressure<br />
required to actuate the VCV depends<br />
on the rating of the rupture disk.<br />
Once the disk ruptures, the hydrostatic<br />
pressure enters the lower air chamber<br />
through the ruptured disk, forcing the<br />
sliding sleeve upward to cover the flow<br />
ports. Operating pressure can be<br />
pump-pressure applied after the VCV is<br />
at the bottom of the well or applied by<br />
hydrostatic pressure when the tool is<br />
run in the hole.<br />
Vann Circulating Valve (VCV) Specifications<br />
Minimum ID<br />
in. (mm)<br />
1.875<br />
(47.62)<br />
2.12<br />
(53.85)<br />
No. <strong>and</strong> ID<br />
of Ports<br />
in. (mm)<br />
4 @ 1.0<br />
(25.4)<br />
6 @ 1.0<br />
(25.4)<br />
Flow Area<br />
of Ports<br />
in. 2 (cm 2 )<br />
3.14<br />
(20.26)<br />
4.71<br />
(30.39)<br />
Makeup<br />
Length<br />
ft (m)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
Vann Circulating<br />
Valve (VCV)<br />
5-98 <strong>Perforating</strong> Solutions<br />
1.96<br />
(0.60)<br />
3.25<br />
(0.99)<br />
15,000<br />
(1035)<br />
15,000<br />
(1035)<br />
*Optional connections are 2 7/8-IF <strong>and</strong> 3 1/2-IF.<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
1,000<br />
(69)<br />
1,000<br />
(69)<br />
HAL15447<br />
Tensile<br />
Strength<br />
lb (kg)<br />
225,000<br />
(102 000)<br />
392,000<br />
(177 700)<br />
Burst<br />
Pressure<br />
psi (bar)<br />
22,000<br />
(1515)<br />
20,000<br />
(1380)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
18,000<br />
(1250)<br />
18,000<br />
(1250)
Automatic Release<br />
The automatic release (AR) allows the perforating guns to<br />
drop immediately after firing.<br />
Features<br />
Can be used with most mechanical <strong>and</strong> pressure-actuated<br />
firing heads<br />
Allows for immediate release of the guns<br />
Leaves the tubing fully open after the guns are released<br />
Eliminates the need to run wireline to shift the guns<br />
Reduces the chance of the gun’s sticking because of debris<br />
Operation<br />
The AR allows for dropping the perforating guns after they<br />
are fired. The guns may be fired either mechanically or by<br />
pressure. The releasing device is actuated by the pressure<br />
generated outside the perforating guns upon detonation, so<br />
the guns are released as soon as they fire.<br />
Automatic Release (AR) Assemblies List<br />
SAP No. Description<br />
Automatic Release (AR)<br />
100005225 2 3/4-in. Auto Release with Mechanical Firing Head<br />
100005226 2 3/4-in. Auto Release with Mechanical Firing Head Model II-D<br />
100005233 3 3/8-in. Auto Release with Mechanical Firing Head<br />
100005234 3 3/8-in. Auto Release with Mechanical Firing Head Model II-D<br />
100155754 3 3/8-in. Auto Release with Mechanical Firing Head Model III-D<br />
100005235 3 3/8 in. Auto Release with 2 1/2-in. TDF<br />
100014158 3 3/8-in. Auto Release-High Pressure with 2 1/2-in. TDF<br />
100010045 3 3/8-in. Auto Release-High Pressure with Mechanical Firing Head<br />
101313281 3 3/8-in. Auto Release Firer with 2 1/2 in. TDF (3 1/2 NK3SB)<br />
100005236 3 1/2-in. Auto Release with Mechanical Firing Head<br />
100156106 3 1/2-in. Auto Release with Mechanical Firing Head Model II-D<br />
101205564 3 1/2-in. Auto Release Firer, Low Pressure with Model II-D<br />
101294470 3 1/2-in. Auto Release Firer with 2 1/2 in. TDF<br />
101313282 3 1/2-in. Auto Release Firer with Model II-D<br />
100155752 4 1/2-in. Auto Release with Mechanical Firing Head Model II-D<br />
101294471 4 1/2-in. Auto Release Firer with 2 1/2 in. TDF<br />
101213155 4 1/2-in. Auto Release Firer Low Pressure with Model II-D<br />
101357916 4 1/2-in. Auto Release Firer with 2 1/2 in. TDF<br />
<strong>Perforating</strong> Solutions 5-99<br />
HAL10512
SAP No.<br />
Automatic Release (AR) Assemblies List<br />
SAP No. Description<br />
101313025 5 1/2-in. Auto Release Firer with Model II-D<br />
101310170 5 1/2-in. Auto Release Firer with Model II-D or III-D<br />
101313059 5 1/2-in. Auto Release Firer with 3 3/8 in. TDF<br />
101357918 5 1/2-in. Auto Release Firer with 2 1/2 in. TDF<br />
Thread Size <strong>and</strong> Type<br />
in. (mm)<br />
100005225 2 3/8 (60.33) EUE 8 Rd<br />
100005226 2 3/8 (60.33) EUE 8 Rd<br />
100005233 2 7/8 (73.03) EUE 8 Rd<br />
100005234 2 7/8 (73.03) EUE 8 Rd<br />
100005235 2 7/8 (73.03) EUE 8 Rd<br />
100155754 2 7/8 (73.03) EUE 8 Rd<br />
100014158 2 7/8 (73.03) EUE 8 Rd<br />
100010045 2 7/8 (73.03) EUE 8 Rd<br />
100005236 3 1/2 (88.90) EUE 8 Rd<br />
100156106 3 1/2 (88.90) EUE 8 Rd<br />
100155752 4 1/2 (114.30) OD Box<br />
101357916 4 1/2 (114.30) OD Box<br />
101294470 3 1/2 (88.90) EUE 8 Rd<br />
101313059 5 1/2 (139.7) TS-3SB Pin<br />
101357918 5 1/2 (139.7) VAM Box<br />
101313281 3 1/2 (88.90) NK3SB Box<br />
101205564 3 1/2 (88.90) EUE 8 Rd<br />
101313282 3 1/2 (88.90) NK3SB Box<br />
100155752 4 1/2 (114.30) OD Blank<br />
101294471 4 1/2 (114.30) OD Blank<br />
101213155<br />
4 1/2 (114.30)<br />
CS Hydril Box<br />
101313025 5 1/2 (139.7) OD Blank<br />
Automatic Release (AR) Specifications<br />
Maximum<br />
OD<br />
in. (mm)<br />
2.88<br />
(73.15)<br />
2.88<br />
(73.15)<br />
3.38<br />
(85.85)<br />
3.38<br />
(85.85)<br />
3.38<br />
(85.85)<br />
3.38<br />
(85.85)<br />
3.38<br />
(85.85)<br />
3.38<br />
(85.85)<br />
3.78<br />
(96.01)<br />
3.78<br />
(96.01)<br />
4.5<br />
(114.30)<br />
4.92<br />
(126)<br />
3.78<br />
(96.01)<br />
5.81<br />
(148)<br />
5.957<br />
(151)<br />
ID After<br />
Release<br />
in. (mm)<br />
2.125<br />
(53.98)<br />
2.125<br />
(53.98)<br />
2.72<br />
(69.09)<br />
2.72<br />
(69.09)<br />
2.72<br />
(69.09)<br />
2.72<br />
(69.09)<br />
2.52<br />
(64.186)<br />
2.52<br />
(64.186)<br />
2.99<br />
(75.95)<br />
2.99<br />
(75.95)<br />
3.67<br />
(93.22)<br />
3.76<br />
(96)<br />
3.00<br />
(76.2)<br />
4.703<br />
(119)<br />
4.70<br />
(119)<br />
Makeup<br />
Length<br />
ft (m)<br />
Maximum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
Minimum<br />
Operating<br />
Pressure<br />
psi (bar)<br />
Maximum<br />
Differential<br />
Pressure<br />
psi (bar)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
5-100 <strong>Perforating</strong> Solutions<br />
2.06<br />
(0.63)<br />
2.06<br />
(0.63)<br />
2.23<br />
(0.68)<br />
2.23<br />
(0.68)<br />
2.23<br />
(0.68)<br />
2.23<br />
(0.68)<br />
2.23<br />
(0.68)<br />
2.23<br />
(0.68)<br />
2.23<br />
(0.68)<br />
2.23<br />
(0.68)<br />
2.23<br />
(0.68)<br />
2.39<br />
(.728)<br />
1.74<br />
(0.53)<br />
1.83<br />
(0.56)<br />
2.39<br />
(0.73)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
20,000<br />
(1380)<br />
13,000<br />
(896)<br />
20,000<br />
(1380)<br />
17,800<br />
(1227)<br />
13,000<br />
(896)<br />
1,500<br />
(103)<br />
1,500<br />
(103)<br />
1,500<br />
(103)<br />
1,500<br />
(103)<br />
1,500<br />
(103)<br />
1,500<br />
(103)<br />
500<br />
(34)<br />
500<br />
(34)<br />
1,500<br />
(103)<br />
1,500<br />
(103)<br />
1,500<br />
(103)<br />
7000<br />
(483)<br />
7000<br />
(483)<br />
4000<br />
(276)<br />
7000<br />
(483)<br />
Contact <strong>Halliburton</strong> TCP Representative<br />
15,000<br />
(1035)<br />
15,000<br />
(1035)<br />
10,000<br />
(690)<br />
10,000<br />
(690)<br />
10,000<br />
(690)<br />
10,000<br />
(690)<br />
17,000<br />
(1170)<br />
17,000<br />
(1170)<br />
10,000<br />
(690)<br />
10,000<br />
(690)<br />
9,500<br />
(655)<br />
6000<br />
(414)<br />
7500<br />
(517)<br />
4700<br />
(324)<br />
4000<br />
(276)<br />
49,500<br />
(22 400)<br />
49,500<br />
(22 400)<br />
68,000<br />
(30 800)<br />
68,000<br />
(30 800)<br />
68,000<br />
(30 800)<br />
68,000<br />
(30 800)<br />
68,000<br />
(30 800)<br />
68,000<br />
(30 800)<br />
68,000<br />
(30 800)<br />
68,000<br />
(30 800)<br />
115,000<br />
(52 100)<br />
87,200<br />
(39 553)<br />
53,300<br />
(24 100)<br />
106,100<br />
(48 100)<br />
106,100<br />
(48 100)
Mechanical Tubing Release<br />
The mechanical tubing release (MTR) provides operators<br />
with the option of keeping or releasing the VannGun®<br />
assembly from the tubing string. The MTR is usually run<br />
above the firing head <strong>and</strong> below the production ports below<br />
the packer. A st<strong>and</strong>ard shifting tool is used to operate the<br />
release mechanism in the MTR.<br />
Features<br />
Frees the tubing for other tools <strong>and</strong> operations such as<br />
logging, production testing, <strong>and</strong> treating<br />
Provides a low-cost way to release the gun assembly<br />
Uses st<strong>and</strong>ard off-the-shelf shifting tools<br />
Does not have a time limit on dropping the gun assembly<br />
Leaves perforations uncovered to eliminate flow<br />
restrictions<br />
Operation<br />
The MTR consists of three main components: the upper<br />
housing, a lower finger release sub, <strong>and</strong> a latch. The latch<br />
retains the finger release sub in the housing. To operate the<br />
MTR, the user must do the following:<br />
1. Select the proper shifting tool <strong>and</strong> run it into the hole<br />
on slickline through the MTR.<br />
2. Pick back up to engage the latch <strong>and</strong> lightly jar the<br />
latch four or five times.<br />
3. Go back down to verify the release of the VannGun<br />
assembly.<br />
SAP No.<br />
(w/o Latch)<br />
100005286<br />
Thread Size <strong>and</strong><br />
Type<br />
in. (mm)<br />
2 3/8 (60.33) EUE<br />
8 Rd Box × Pin<br />
Mechanical Tubing Release (MTR) Specifications<br />
Maximum OD<br />
in. (mm)<br />
3.06<br />
(77.22)<br />
Minimum ID<br />
(Latch Size)<br />
in. (mm)<br />
1.50<br />
(38.10)<br />
1.63<br />
(41.40)<br />
1.81<br />
(45.97)<br />
1.88<br />
(760)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
111,500<br />
(50 576)<br />
Mechanical Tubing Release (MTR)<br />
<strong>Perforating</strong> Solutions 5-101<br />
HAL15435<br />
Burst<br />
Pressure<br />
psi (bar)<br />
12,000<br />
(825)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
10,000<br />
(690)<br />
Makeup<br />
Length<br />
ft (m)<br />
1.50<br />
(0.46)
SAP No.<br />
(w/o Latch)<br />
100005281<br />
100005284<br />
101236790<br />
101435633<br />
101398862<br />
101399826<br />
101327124<br />
Latch Size<br />
in. (mm)<br />
1.50<br />
(38.10)<br />
1.625<br />
(41.28)<br />
1.81<br />
(45.97)<br />
1.88<br />
(47.75)<br />
2.25<br />
(57.15)<br />
2.125<br />
(53.98)<br />
2.75<br />
(69.85)<br />
3.69<br />
(93.73)<br />
3.562<br />
(90)<br />
4.313<br />
(110)<br />
Thread Size <strong>and</strong><br />
Type<br />
in. (mm)<br />
2 7/8 (73.03) EUE<br />
8 Rd Box × Pin<br />
3 1/2 (88.9) EUE<br />
8 Rd Box × Pin<br />
5 (127) 15 lb (6.8 kg)<br />
New Vam Box × Pin<br />
5 1/2-17.00 Vam Top<br />
HC Box X Pin<br />
Threads, 13 Chrome<br />
4 1/2-12.6 Vam Top<br />
Threads, 13 Chrome<br />
5 1/2-15.5 Vam Top<br />
Threads, 13 Chrome<br />
4 1/2-12.6 Vamace<br />
Box X Pin,<br />
13 Chrome<br />
Mechanical Tubing Release (MTR) Specifications<br />
3.38<br />
(85.85)<br />
3.95<br />
(100.33)<br />
5.59<br />
(142.01)<br />
6.50<br />
(165)<br />
5.50<br />
(140)<br />
6.50<br />
(165)<br />
5.50<br />
(140)<br />
1.88<br />
(47.75)<br />
2.13<br />
(53.98)<br />
2.25<br />
(57.15)<br />
111,500<br />
(50 576)<br />
2.25<br />
(57.15) 111,500<br />
2.75<br />
(69.85)<br />
3.69<br />
(93.68)<br />
4.313<br />
(110)<br />
3.562<br />
(90)<br />
4.313<br />
(110)<br />
3.562<br />
(90)<br />
(50 576)<br />
111,500<br />
(50 576)<br />
168,000<br />
(76 200)<br />
107,000<br />
(48,500)<br />
168,000<br />
(76,200)<br />
107,000<br />
(48,500)<br />
5-102 <strong>Perforating</strong> Solutions<br />
12,000<br />
(825)<br />
11,000<br />
(760)<br />
12,000<br />
(825)<br />
6,800<br />
(469)<br />
6,300<br />
(434)<br />
6,400<br />
(441)<br />
6,300<br />
(434)<br />
Mechanical Tubing Release (MTR) Shifting Tool <strong>and</strong> Key Number<br />
Tool No.<br />
SAP No.<br />
42 BO 245<br />
101059081<br />
42 BO 121<br />
12005796<br />
42 BO 117<br />
101059064<br />
42 BO 237<br />
101059079<br />
42 BO 116<br />
100008775<br />
42 BO 117<br />
101059064<br />
42 BO 237<br />
101059079<br />
42 BO 118<br />
100008776<br />
42 BO 159<br />
101015719<br />
42 BO 146<br />
100009659<br />
42 BO 238<br />
101010057<br />
Maximum OD<br />
in. (mm)<br />
Key No.<br />
SAP No.<br />
42 B 818<br />
101282505<br />
42 B 80<br />
101059269<br />
42 B 37<br />
101059122<br />
42 B 681<br />
101059193<br />
42 B 153<br />
101059090<br />
42 B 37<br />
101059122<br />
42 B 681<br />
101059193<br />
42 B 287<br />
101059109<br />
42 B 387<br />
101059133<br />
42 B 349<br />
101059118<br />
42 B 707<br />
101059204<br />
101399752 101399753<br />
101399109 101399113<br />
Minimum ID<br />
(Latch Size)<br />
in. (mm)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
Key Maximum Exp. OD<br />
in. (mm)<br />
1.64<br />
(41.65)<br />
1.89<br />
(48.006)<br />
2.076<br />
(52.73)<br />
2.156<br />
(54.76)<br />
2.108<br />
(53.569)<br />
2.076<br />
(52.73)<br />
2.156<br />
(54.76)<br />
2.592<br />
(65.837)<br />
2.49<br />
(63.25)<br />
3.156<br />
(80.16)<br />
4.15<br />
(105.41)<br />
Burst<br />
Pressure<br />
psi (bar)<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
11,000<br />
(760)<br />
10,000<br />
(690)<br />
11,000<br />
(760)<br />
5,000<br />
(345)<br />
6,000<br />
(414)<br />
4,000<br />
(276)<br />
6,000<br />
(414)<br />
Key Minimum OD<br />
in. (mm)<br />
1.49<br />
(37.85)<br />
1.62<br />
(41.148)<br />
1.75<br />
(44.45)<br />
1.69<br />
(42.93)<br />
1.84<br />
(46.74)<br />
1.750<br />
(44.45)<br />
1.69<br />
(42.93)<br />
2.156<br />
(54.762)<br />
1.97<br />
(50.04)<br />
2.718<br />
(69.037)<br />
3.67<br />
(93.218)<br />
Makeup<br />
Length<br />
ft (m)<br />
1.63<br />
(0.50)<br />
1.88<br />
(0.57)<br />
3.60<br />
(1.10)<br />
4.7<br />
(1.4)<br />
4.1<br />
(1.25)<br />
4.8<br />
(1.46)<br />
4.1<br />
(1.25)
Pressure-Actuated Tubing Release<br />
The pressure-actuated tubing release (PATR) is used to<br />
separate the guns from the toolstring when mechanical or<br />
slickline devices are not desirable. When separated, the guns<br />
drop off of the production tubing. Once the guns drop away,<br />
other tools <strong>and</strong> operations have no restrictions through the<br />
end of the tubing. In fact, the housing attached to the string<br />
has a greater ID than the tubing.<br />
Features<br />
Leaves the tubing string fully open<br />
Ideal for use in remote areas where wireline is expensive<br />
or unavailable<br />
Ideal for situations where wireline can cause a safety<br />
hazard<br />
Provides access to the wellbore for production logging<br />
tools<br />
Especially suited for releasing guns prior to stimulation<br />
treatments<br />
Operation<br />
The PATR consists of four main components: an upper<br />
housing, lower finger release sub, inner sleeve, <strong>and</strong> retaining<br />
latch. The PATR is pressure-balanced until the st<strong>and</strong>ing valve<br />
is dropped into the inner sleeve.<br />
Tubing pressure is applied to shear the retaining pins in the<br />
latch. Once the latch has been shifted, the finger release sub<br />
with the sleeve releases from the housing <strong>and</strong> drops the<br />
perforating assembly into the rathole.<br />
SAP No.<br />
100156751<br />
100156744<br />
101015385<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 3/8 (60.33) EUE<br />
8 Rd Box × Pin<br />
2 7/8 (73.03) EUE<br />
8 Rd Box × Pin<br />
3 1/2 (88.9) EUE<br />
8 Rd Box × Pin<br />
Pressure-Actuated Tubing<br />
Release (PATR)<br />
Pressure-Actuated Tubing Release (PATR) Specifications<br />
Maximum OD<br />
in. (mm)<br />
3.38<br />
(85.85)<br />
3.75<br />
(95.25)<br />
4.19<br />
(106.43)<br />
Minimum ID<br />
Before<br />
Release<br />
in. (mm)<br />
1.63<br />
(41.40)<br />
1.812<br />
(46.02)<br />
1.812<br />
(46.02)<br />
Minimum ID<br />
After<br />
Release<br />
in. (mm)<br />
2.31<br />
(58.67)<br />
2.828<br />
(71.83)<br />
3.5<br />
(88.90)<br />
<strong>Perforating</strong> Solutions 5-103<br />
HAL15442<br />
St<strong>and</strong>ing<br />
Valve OD<br />
in. (mm)<br />
1.76<br />
(44.70)<br />
1.86<br />
(47.24)<br />
1.86<br />
(47.24)<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
Makeup<br />
Length<br />
ft (m)<br />
1.73<br />
(0.53)<br />
1.72<br />
(0.52)<br />
1.71<br />
(0.52)<br />
Tensile<br />
Strength<br />
lb (kg)<br />
90,000<br />
(40 800)<br />
120,000<br />
(54 400)<br />
130,000<br />
(58 900)<br />
HAL10531<br />
St<strong>and</strong>ing Valve<br />
Burst<br />
Pressure<br />
psi (bar)<br />
10,000<br />
(670)<br />
10,000<br />
(670)<br />
10,000<br />
(670)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
9,000<br />
(620)<br />
10,000<br />
(670)<br />
10,000<br />
(670)
DPU ® Downhole Power Unit<br />
The DPU® downhole power unit firing head is an<br />
electromechanical device that is designed to produce a linear<br />
force that activates a pressure-assisted firing device. The<br />
pressure-assisted device fires the perforating guns. Before the<br />
DPU firing head was used to activate the pressure-assisted<br />
firing device, this type of perforating gun activation was run<br />
on tubing. The pressure-assisted firing device was previously<br />
activated by dropping a device from the surface. The DPU<br />
firing head is run on slickline.<br />
For the DPU firing head to begin activation, several<br />
parameters must be present.<br />
Pressure setting: The DPU firing head has a surfaceselected<br />
downhole pressure setting that must be met. Any<br />
time the well pressure at the DPU firing head drops below<br />
the selected pressure setting, the DPU firing head<br />
activation sequence is stopped<br />
Downhole Temperature: The DPU firing head requires a<br />
precise surface-selected downhole temperature. Any time<br />
the well temperature drops below the selected temperature<br />
setting, the DPU firing head activation sequence is stopped<br />
Tool Movement: The DPU firing head has an<br />
accelerometer that detects tool movement. If the<br />
accelerometer detects motion, the other operating<br />
parameters are inactive<br />
Surface-Selected Timer: The DPU firing head has a<br />
surface-selected timer that is activated if the three previous<br />
parameters are present<br />
If these four parameters are present, the DPU firing head is<br />
activated <strong>and</strong> the rod begins to stroke out. Rod travel takes<br />
approximately 20 minutes before contracting the pressureassisted<br />
firing device. When the DPU firing head rod<br />
contacts the pressure-assisted firing device, a pin is sheared<br />
<strong>and</strong> perforating is activated. After initial activation, the DPU<br />
runs for 25 minutes <strong>and</strong> then turns off.<br />
The 3.66 OD DPU <strong>and</strong> 2.50-in. DPU firing head can be<br />
converted to run either the Model II-D or the Model III-D<br />
pressure-assisted firing heads.<br />
Fish Neck<br />
Pressure<br />
Temperature<br />
Switch<br />
Firing Head<br />
PC Board<br />
®<br />
DPU<br />
Downhole<br />
Power Unit<br />
DPU Power<br />
Rod<br />
Push Guide<br />
Model III<br />
Firing Head<br />
Adapter<br />
to Guns<br />
Conversion Kits for DPU ® Downhole Power Unit<br />
Assembly No. SAP No.<br />
146DFH20 00050531<br />
146DFH11 00050462<br />
Maximum OD<br />
in. (mm)<br />
3.66<br />
(93.96)<br />
2.50<br />
(64.50)<br />
5-104 <strong>Perforating</strong> Solutions<br />
HAL15990<br />
HAL15988<br />
DPU® Downhole Power<br />
Unit<br />
®<br />
DPU Power<br />
Rod<br />
Push Guide<br />
Model III<br />
Firing Head<br />
Adapter<br />
to Guns
SmartETD ® Advanced Electronic Triggering Device<br />
The SmartETD® tool is an advanced<br />
electronic triggering device that<br />
provides an accurate, safe, <strong>and</strong> reliable<br />
method to run <strong>and</strong> fire downhole<br />
explosive tools using slickline. With its<br />
built-in sensor <strong>and</strong> memory<br />
capabilities, it can record <strong>and</strong> store<br />
downhole temperature <strong>and</strong> pressure<br />
data that can be used by the slickline<br />
specialists to program firing<br />
parameters.<br />
The SmartETD tool requires four<br />
parameters to be met prior to firing.<br />
These are motion, time (preset),<br />
pressure (preset), <strong>and</strong> temperature<br />
(preset). The timing sequence begins<br />
when the tool is exposed to pressure.<br />
After the tool stops, any motion resets<br />
the electronic timer. After the<br />
SmartETD timer has remained<br />
motionless for a specific period of<br />
time <strong>and</strong> has simultaneously<br />
encountered the preset temperature<br />
<strong>and</strong> pressure windows, it initiates the<br />
firing sequence. The SmartETD tool<br />
can log memory settings for pressure<br />
<strong>and</strong> temperature readings up to 12k<br />
data sets.<br />
The SmartETD tool will fire the<br />
<strong>Halliburton</strong> rig environment RED®<br />
detonator, as well as<br />
API RP-67-compliant devices. It is<br />
also capable of resisting detonation.<br />
SmartETD ® Specifications<br />
SAP No.<br />
Diameter<br />
in. (mm)<br />
Length<br />
in. (mm)<br />
Max. Temperature<br />
°F (°C)<br />
Max. Pressure<br />
psi (bar)<br />
Features<br />
Control Parameters<br />
101038328<br />
146ETD14<br />
Optional No-Blow<br />
No-Drop Assembly<br />
1.690<br />
(42.93)<br />
60<br />
(1524)<br />
<strong>Perforating</strong> Solutions 5-105<br />
300<br />
(149)<br />
15,000<br />
(103.42)<br />
Pressure yes (programmable)<br />
Temperature yes (programmable)<br />
Time yes (programmable)<br />
Motion yes<br />
Tension no<br />
Resist Detonation<br />
Capability<br />
yes<br />
HES RED ® Capability yes<br />
Memory Logging<br />
Pressure yes<br />
Temperature yes<br />
No. of Points (reading) 12k data sets<br />
HAL15398<br />
SmartETD® Tool<br />
No-Blow, No Drop<br />
Assembly<br />
Top Shock/Centralizer<br />
Quick Lock Assembly<br />
®<br />
Smart ETD Tool<br />
HV Shooting Module<br />
Adapter<br />
Selectable Mechanical<br />
Pressure Switch<br />
Shock Absorber<br />
Detonator<br />
Sub/Explosives<br />
as required with<br />
STD 13/8-in. GO<br />
Connection<br />
®<br />
VannGun Assembly
Y-Block Assembly<br />
The Y-block assembly is used in dual completions <strong>and</strong><br />
single selective completions to attach or hang guns from<br />
the long string.<br />
In single selective completions, this installation is run either<br />
for selectively shooting <strong>and</strong> testing two zones or for<br />
production when the application requires the option of<br />
producing two zones separately through one tubing string.<br />
In dual completions, the assembly allows for the elimination<br />
of the tail pipe between the dual packer <strong>and</strong> the gun.<br />
The Y-block assembly is available as a ported or non-ported<br />
assembly. The ported Y-block allows guns to be fired upon<br />
applying pressure to the long string. In the non-ported<br />
assembly, there is no communication between the long string<br />
<strong>and</strong> the short string.<br />
HAL10578<br />
Non-Ported Ported<br />
Y-block assemblies are custom-made according to the casing ID, the<br />
tubing size <strong>and</strong> type, <strong>and</strong> the gun size. Consult your local<br />
<strong>Halliburton</strong> representative for ordering information.<br />
Retrievable<br />
Packer<br />
Sliding-Side Door ®<br />
Y-Block<br />
®<br />
VannGun<br />
Assembly<br />
Time-Delay Firer<br />
Hydraulic<br />
Packer<br />
Nipple<br />
5-106 <strong>Perforating</strong> Solutions<br />
HAL8139<br />
Y-Block Assembly<br />
Vent<br />
Tubing Release<br />
Mechanical Firing<br />
Head<br />
VannGun<br />
Assembly<br />
Time-Delay Firer
Gun Guides<br />
Gun guides were developed by <strong>Halliburton</strong> to maintain the<br />
proper orientation of guns attached to the short string in a<br />
dual completion. The gun orientation must be maintained<br />
so that the charges shoot away from the long string. Gun<br />
guides are also used with Y-blocks in dual-string <strong>and</strong><br />
single-string completions.<br />
There are two types of gun guides. The delta-shaped or dual<br />
gun guide can be used when the casing ID is the same from<br />
top to bottom. If the casing at the top of the well is larger,<br />
then the wraparound guide must be used. The wraparound<br />
type may also be used in the wellbores with the same ID top<br />
to bottom.<br />
Guides are available for most of the smaller size guns<br />
(3 3/8 in. or 85.73 mm <strong>and</strong> smaller) that are typically run on<br />
the short string side of a dual completion.<br />
HAL6190<br />
HAL10577<br />
Dual Completion with Wraparound<br />
Gun Guide<br />
Dual Completion with<br />
Dual Gun Guide<br />
Dual Completion<br />
with Gun Guides<br />
®<br />
VannGun<br />
Assemblies<br />
Gun Guide<br />
VannGun<br />
Assemblies<br />
Gun Guide<br />
VannGun<br />
Assemblies<br />
Time-Delay<br />
Firing Head<br />
Permanent or<br />
Retrievable Packer<br />
Tubing Release<br />
Mechanical<br />
Firing Head<br />
VannGun<br />
Assemblies<br />
<strong>Perforating</strong> Solutions 5-107<br />
HAL15395<br />
Dual Hydraulic<br />
Set Packer<br />
Balanced<br />
Isolation Tool<br />
Time-Delay<br />
Firing Head
Hydraulic Metering Release Tool for the Single Trip System (STPP-GH) Tool<br />
The hydraulic metering release tool is one component of the<br />
single trip system that allows us to perforate <strong>and</strong> frac-pack a<br />
zone of interest in a single trip.<br />
Numerous safety <strong>and</strong> economic benefits accompany this<br />
capability. These benefits become even more profound as<br />
well parameters become more severe. The ever-present goal<br />
is to reduce completion CAPEX <strong>and</strong> maximize net present<br />
value.<br />
Features<br />
Save rig time with reduced pipe trips for faster<br />
completions<br />
Minimize fluid loss <strong>and</strong> formation damage<br />
Minimize associated well control risks<br />
Perforate under- or overbalanced<br />
Perform the s<strong>and</strong> control option most suitable for your<br />
well (FP, HRWF, GP)<br />
Complete deep, hot zones where fluid loss pills are not<br />
effective<br />
5-108 <strong>Perforating</strong> Solutions<br />
HAL15780<br />
Plug<br />
Hydraulic Metering<br />
Release Tool<br />
Floating Piston<br />
Metering Section<br />
Silicone Fluid<br />
Finger Release<br />
Stinger/Fishneck<br />
Shear Screws
Upper<br />
Thread<br />
Size <strong>and</strong><br />
Type<br />
2 7/8<br />
EU-RD<br />
Lower<br />
Thread<br />
Size <strong>and</strong><br />
Type<br />
N/A<br />
Hydraulic Metering Release Assembly (Low Temperature)<br />
Overall<br />
Length<br />
in. (cm)<br />
45.47<br />
(115.49)<br />
Maximum<br />
OD<br />
in. (cm)<br />
4.5<br />
(11.43)<br />
Effective<br />
OD*<br />
in. (cm)<br />
4.5<br />
(11.43)<br />
5.5<br />
(13.97)<br />
7.5<br />
(19.05)<br />
Temperature<br />
Rating<br />
°F (°C)<br />
200<br />
(93.33)<br />
*Effective OD of the tool is dictated by the OD of the skirt to be used.<br />
**Maximum weight on gun hanger = gun weight + slackoff weight on hydraulic release tool.<br />
***The tool is assembled with four shear screws of 3,400 lb each.<br />
Upper<br />
Thread<br />
Size <strong>and</strong><br />
Type<br />
2 7/8<br />
EU-RD<br />
Lower<br />
Thread<br />
Size <strong>and</strong><br />
Type<br />
N/A<br />
Tensile<br />
Rating<br />
lb (kg)<br />
97,700<br />
(44 315)<br />
Maximum<br />
Slack Off<br />
Weight on<br />
Tool<br />
lb (kg)<br />
30,000<br />
(13 607)<br />
Minimum<br />
Slack Off<br />
Weight on<br />
Tool<br />
lb (kg)<br />
13,600<br />
(6168)<br />
Hydraulic Metering Release Assembly (High Temperature)<br />
Overall<br />
Length<br />
in. (cm)<br />
45.47<br />
(115.49)<br />
Maximum<br />
OD<br />
in. (cm)<br />
4.5<br />
(11.43)<br />
Effective<br />
OD*<br />
in. (cm)<br />
4.5<br />
(11.43)<br />
5.5<br />
(13.97)<br />
7.5<br />
(19.05)<br />
Temperature<br />
Rating<br />
°F (°C)<br />
200-350<br />
(93.33-148.88)<br />
*Effective OD of the tool is dictated by the OD of the skirt to be used.<br />
**Maximum weight on gun hanger = gun weight + slackoff weight on hydraulic release tool.<br />
***The tool is assembled with four shear screws of 3,400 lb each.<br />
Tensile<br />
Rating<br />
lb (kg)<br />
97,700<br />
(44 315)<br />
Maximum<br />
Slack off<br />
Weight on<br />
Tool<br />
lb (kg)<br />
30,000<br />
(13 607)<br />
Minimum<br />
Slackoff<br />
Weight on<br />
Tool<br />
lb (kg)<br />
13,600<br />
(6168)<br />
Redressable<br />
<strong>Perforating</strong> Solutions 5-109<br />
Yes<br />
Redressable<br />
Yes<br />
Weight<br />
lb (kg)<br />
156.46<br />
(70.96)<br />
Weight<br />
lb (kg)<br />
156.46<br />
(70.96)
Fast Gauge Recorder<br />
The fast gauge recorder is a downhole<br />
gauge that records important pressure<br />
<strong>and</strong> temperature data in high-pressure,<br />
severe shock/vibration environments.<br />
This gauge is typically used with<br />
StimGun* assemblies or<br />
StimTube* tools. The pressure<br />
profile collected is used to verify<br />
proper propellant burn as well as<br />
determine the fracturing response of<br />
the formation by analyzing post-job<br />
data with PulsFrac** software.<br />
The data the fast gauge recorder collects<br />
can be used to determine whether or<br />
not the job was executed properly, to<br />
validate computer models, <strong>and</strong> to make<br />
initial determinations of rock<br />
properties. The data can also be used to<br />
estimate fracture gradients.<br />
The fast gauge recorder can perform<br />
within the rigors of perforating<br />
applications by withst<strong>and</strong>ing shock<br />
loads of 100,000 g. The tool collects <strong>and</strong><br />
records 115,000 data points per second<br />
to give exceptionally accurate <strong>and</strong><br />
reliable information.<br />
The programmable multi-speed feature<br />
allows flexibility in collecting pressure,<br />
acceleration, <strong>and</strong> vibration data at<br />
various sampling speeds <strong>and</strong> time<br />
intervals. The gauge starts sampling at a<br />
slow speed <strong>and</strong> when a pressure pulse<br />
or acceleration/vibration event occurs,<br />
the gauge automatically switches to a<br />
high sampling speed, then back to an<br />
intermediate speed, <strong>and</strong> finally back to<br />
a slow sampling speed. The process can<br />
be repeated until the memory is full.<br />
Each gauge includes a shock mitigator<br />
which isolates the gauge from the tool,<br />
reducing shock <strong>and</strong> vibration (up to a<br />
factor of 10) that occurs when the gun<br />
ignites. Use of the shock mitigator<br />
lengthens the life of the recorder,<br />
battery, <strong>and</strong> sensors.<br />
A special application of the 1 11/16-in.<br />
(42.86 mm) OD gauge is its use as a<br />
“drop bar” to fire a propellant or<br />
perforating gun. The gauge can be used<br />
with firing pin <strong>and</strong> fishneck<br />
attachments as the drop bar to trigger a<br />
gun firing head. It can be left there as<br />
long as necessary to collect pressure<br />
flow data. With this feature, the<br />
customer can retrieve pressure data<br />
from the gun <strong>and</strong> also determine if the<br />
gun actually fired.<br />
Fast Gauge<br />
Recorder<br />
*StimTube <strong>and</strong> StimGun are trademarks of<br />
Marathon Oil Company.<br />
**PulsFrac is a trademark of John F. Schatz<br />
Research <strong>and</strong> Consulting, Inc.<br />
5-110 <strong>Perforating</strong> Solutions<br />
HAL15464
Features<br />
Shock-hardened design<br />
High sampling speed<br />
Records pressure, acceleration, vibration, <strong>and</strong><br />
temperature<br />
Programmable low, intermediate, <strong>and</strong> high speeds <strong>and</strong><br />
time intervals<br />
Can be used as drop bar pressure gauge<br />
Computer programming <strong>and</strong> data readout<br />
Internal microprocessor control<br />
Automatic sensor testing <strong>and</strong> balancing<br />
Selectable pressure, temperature, <strong>and</strong> acceleration/<br />
vibration ranges<br />
Gauge Dimensions<br />
Maximum<br />
Acceleration<br />
<strong>and</strong> Vibration<br />
1 11/16 in. OD × 50 in.<br />
± 50,000 g<br />
(22 lb)<br />
*Windows 2000 or NT is recommended.<br />
Sampling Rate<br />
115,000 points/second<br />
down to one sample every<br />
10 seconds<br />
Fast Gauge Recorder Specifications<br />
Current Drain<br />
500 uA sleeping<br />
100 mA sampling<br />
Temperature Range<br />
°F (°C)<br />
-40 to 248<br />
(-40 to 120)<br />
Computer/<br />
Communications<br />
750 MHz or greater PC,<br />
with st<strong>and</strong>ard RS-232<br />
Pressure Range<br />
psi (bar)<br />
35,000 (2413) peak<br />
15,000 (1034) continuous<br />
Measures tool movement <strong>and</strong> acceleration/vibration up<br />
to ±50,000 g<br />
Current <strong>and</strong> internal/battery voltage readouts to verify<br />
proper gauge operation<br />
Internal temperature <strong>and</strong> battery data<br />
Selectable sampling rates up to 115,000 data points<br />
per second<br />
Auto stop/start recording modes<br />
Includes shock mitigator<br />
Up to 1,048,756 data points of memory<br />
Uses low-cost st<strong>and</strong>ard AA alkaline or lithium batteries<br />
Software<br />
Sensor<br />
Frequency<br />
Response<br />
Windows 98* 0 to 10,000 Hz<br />
Data Resolution Memory Capacity<br />
12 bits @ 115,000<br />
data points/second<br />
Power Requirements<br />
6 to 12 volts, AA<br />
alkaline or lithium cells<br />
1,048,576 data points<br />
<strong>Perforating</strong> Solutions 5-111
Gamma Perforator Logging Tool<br />
The gamma perforator is a ruggedized depth correlation tool<br />
designed specifically for operation with explosive equipment,<br />
such as perforating guns, packers <strong>and</strong> plugs, <strong>and</strong> coring guns.<br />
The tool can operate in liquid or gas-filled, openhole or cased<br />
hole wells. The gamma perforator is available in two sizes:<br />
3.375-in. <strong>and</strong> 1.687-in. version.<br />
The gamma perforator is not intended to provide a<br />
calibrated gamma measurement. No borehole corrections are<br />
performed in the algorithms, <strong>and</strong> calibration procedures are<br />
only used to ensure that the tool is working properly before<br />
<strong>and</strong> after jobs.<br />
The tool has a built-in shock absorber system <strong>and</strong> does not<br />
require an external shock sub. In addition, the electronic<br />
components are covered with silicon potting to help dampen<br />
the shock wave that impacts components. All sub-assemblies<br />
required for perforating with different connections must be<br />
ordered individually.<br />
Tool Length<br />
GPLT<br />
GPST<br />
Length<br />
ft (m)<br />
5.03<br />
(1.5)<br />
6.23<br />
(1.9)<br />
Gamma Perforator Logging Tool Specifications<br />
Diameter<br />
in. (mm)<br />
3.375<br />
(85.7)<br />
1.69<br />
(42.9)<br />
Features<br />
Offers three configurations:<br />
– Normal perforating <strong>and</strong> plug setting<br />
– St<strong>and</strong>-alone gamma/CCL-correlation<br />
– Side wall coring<br />
High resistance minimizes accidental firing risks<br />
Slimhole version allows perforating operations to be<br />
performed without the need to pull tubing from the well<br />
Maximum Pressure<br />
psi (Mpa)<br />
20,000<br />
(137.9)<br />
18,000<br />
(124.1)<br />
Maximum Temperature<br />
°F (°C)<br />
350<br />
(176.7)<br />
350<br />
(176.7)<br />
Weight<br />
lb (kg)<br />
82<br />
(37.2)<br />
35<br />
(15.9)<br />
5-112 <strong>Perforating</strong> Solutions
Detonators<br />
Capsule RED ® Detonators<br />
The capsule RED® detonator is an<br />
advanced electro-explosive device<br />
designed for use with capsule<br />
perforating guns <strong>and</strong> other explosive<br />
devices where a pressure-resistant<br />
detonator is required. The design<br />
features of the capsule RED detonator<br />
provides significantly improved safety<br />
characteristics over conventional<br />
resistorized devices <strong>and</strong> allows wellsite<br />
activities to continue uninterrupted<br />
while perforating.<br />
Features<br />
Does not use primary explosives<br />
Redundant electrical components<br />
for enhanced safety<br />
Ceramic firing capacitors for<br />
enhanced reliability<br />
Surface-mount circuit technology<br />
for ruggedness<br />
Metal housing for radio frequency<br />
shielding<br />
High-output explosive load <strong>and</strong><br />
flyer plate for enhanced reliable<br />
detonation transfer<br />
Dual sealing methods at top of<br />
detonator<br />
Patented sealing for detonating cord<br />
interface<br />
Specifications<br />
No-fire voltage level: 120 VDC<br />
Firing voltage: 155 to 190 VDC<br />
(nominal 175 VDC)<br />
Recommended firing method:<br />
“Dump firing.” Deliver 250 VDC to<br />
the firing head<br />
Recommended firing polarity:<br />
positive or negative DC<br />
Requirements for radio silence<br />
waivers:<br />
– Transmitters with power less<br />
than 1 watt = no exclusion<br />
area<br />
– H<strong>and</strong>held RF transmitters<br />
(cell phones <strong>and</strong> walkietalkies)<br />
operation—<br />
minimum distance radius<br />
from explosive workplace =<br />
no minimum distance<br />
restriction<br />
– All other RF sources (l<strong>and</strong> or<br />
offshore, mobile or fixed)<br />
operation—minimum<br />
distance radius from<br />
explosive workplace = no<br />
minimum distance<br />
restriction<br />
– Offshore workboats (or other<br />
1-MHz, 1,000 watt or above<br />
transmitters) operation—<br />
minimum distance radius<br />
from explosive workplace =<br />
no minimum distance<br />
restriction<br />
– Stray voltage measurement,<br />
electric welding operation, or<br />
electrical cathodic protection<br />
systems = operation<br />
acceptable if stray voltage is<br />
less than 2 V<br />
Bleed-off time with power removed:<br />
5 sec<br />
Semi-conductor bridge (SCB)<br />
resistance: 2 ohms<br />
No-fire DC power dissipation<br />
(st<strong>and</strong>-alone SCB without circuit):<br />
5 watts minimum<br />
Energetic materials:<br />
– Ignition pyrotechnic mix =<br />
50 mg THKP<br />
– Transition column = 400 mg<br />
HMX<br />
– Output pellet = 500 mg<br />
HMX<br />
Environmental rating: 375°F at<br />
15,000 psi for one hour<br />
UN shipping classification: 1.4S<br />
Capsule RED® Detonator<br />
<strong>Perforating</strong> Solutions 5-113<br />
HAL9251
RED ® GO-Style Thermal Igniter<br />
The RED® igniter is an advanced<br />
electro-explosive device used to initiate<br />
gas-generating power charges inside<br />
oilfield setting tools. The design<br />
features of the RED igniter provide<br />
significantly improved safety<br />
characteristics over conventional<br />
resistorized devices <strong>and</strong> allow many<br />
wellsite activities to continue<br />
uninterrupted while using power<br />
setting tools.<br />
Features<br />
Mates with top subs <strong>and</strong> adapters<br />
for industry st<strong>and</strong>ard setting tools<br />
Redundant electrical components<br />
for enhanced safety<br />
Multiple ceramic firing capacitors<br />
for reliability<br />
Surface-mount circuit technology<br />
for ruggedness<br />
Thermally conductive semiconductor<br />
bridge for stray power<br />
dissipation<br />
Metal housing for radio frequency<br />
shielding<br />
Thin aluminum end-closure for low<br />
debris characteristics<br />
Specifications<br />
No-fire voltage level: 120 VDC<br />
Firing voltage: 155 to 190 VDC<br />
(nominal 175 VDC)<br />
Recommended firing method:<br />
“Dump firing.” Deliver 250 VDC to<br />
the firing head<br />
Recommended firing polarity:<br />
positive or negative DC<br />
Requirements for radio silence<br />
waivers:<br />
– Transmitters with power less<br />
than 1 watt = no exclusion<br />
area<br />
– H<strong>and</strong>held RF transmitters<br />
(cell phones <strong>and</strong> walkietalkies)<br />
operation—<br />
minimum distance radius<br />
from explosive workplace =<br />
no minimum distance<br />
restriction<br />
– All other RF sources (l<strong>and</strong> or<br />
offshore, mobile or fixed)<br />
operation—minimum<br />
distance radius from<br />
explosive workplace = no<br />
minimum distance<br />
restriction<br />
– Offshore workboats (or other<br />
1-MHz, 1,000 watt or above<br />
transmitters) operation—<br />
minimum distance radius<br />
from explosive workplace =<br />
no minimum distance<br />
restriction<br />
– Stray voltage measurement,<br />
electric welding operation, or<br />
electrical cathodic protection<br />
systems = operation<br />
acceptable if stray voltage is<br />
less than 2 V<br />
Bleed-off time with power removed:<br />
5 sec<br />
SCB resistance: 2 ohms<br />
SCB no-fire power dissipation:<br />
5 watts minimum<br />
Energetic materials:<br />
– Ignition pyrotechnic mix =<br />
150 mg THKP pressed in<br />
SCB header<br />
– Main load = .15 gm FFFG<br />
black powder <strong>and</strong> .75 gm<br />
THKP loose powders<br />
Temperature rating: 375°F for one<br />
hour<br />
UN shipping classification: 1.4G<br />
RED® GO-Style Thermal Igniter<br />
5-114 <strong>Perforating</strong> Solutions<br />
HAL11756
Block RED ® Detonators<br />
The block RED® detonator is an advanced electro-explosive<br />
device used to initiate perforating guns. The design features<br />
of the block RED detonator provide significantly improved<br />
safety characteristics over conventional resistorized devices<br />
<strong>and</strong> allow wellsite activities to continue uninterrupted while<br />
perforating.<br />
Features<br />
Does not use primary explosives<br />
Redundant electrical components for enhanced safety<br />
Ceramic firing capacitors for enhanced reliability<br />
Surface-mount circuit technology for ruggedness<br />
Metal housing for radio frequency shielding<br />
High-output explosive load <strong>and</strong> flyer plate for enhanced<br />
reliable detonation transfer<br />
Fluid-disabled to prevent gun damage in the event of a<br />
seal failure<br />
Specifications<br />
No-fire voltage level: 120 VDC<br />
Firing voltage: 155 to 190 VDC (nominal 175 VDC)<br />
Recommended firing method: “Dump firing.” Deliver<br />
250 VDC to the firing head<br />
Recommended firing polarity: positive or negative DC<br />
Requirements for radio silence waivers:<br />
– H<strong>and</strong>held RF transmitters (cell phones <strong>and</strong><br />
walkie-talkies) operation—minimum distance<br />
radius from explosive workplace = no minimum<br />
distance restriction<br />
– All other RF sources (l<strong>and</strong> or offshore, mobile or<br />
fixed) operation—minimum distance radius from<br />
explosive workplace = no minimum distance<br />
restriction<br />
– Offshore workboats (or other 1-MHz, 1,000 watt<br />
or above transmitters) operation—minimum<br />
distance radius from explosive workplace = no<br />
minimum distance restriction<br />
– Stray voltage measurement, electric welding<br />
operation, or electrical cathodic protection<br />
systems = operation acceptable if stray voltage is<br />
less than 2 V<br />
Bleed-off time with power removed: 5 sec<br />
SCB resistance: 2 ohms<br />
SCB no-fire power dissipation: 5 watts minimum<br />
Energetic materials:<br />
– Ignition pyrotechnic mix = 50 mg THKP<br />
– Transition column = 400 mg HMX<br />
– Output pellet = 500 mg HMX<br />
Temperature rating: 375°F for one hour<br />
UN shipping classification: 1.4S<br />
Block RED® Detonator<br />
<strong>Perforating</strong> Solutions 5-115<br />
HAL11412
Top Fire RED ® Detonators<br />
The top fire RED® detonator is an advanced electroexplosive<br />
device used to initiate perforating guns, jet cutters,<br />
<strong>and</strong> severing tools. The design features of the top fire RED<br />
detonator provide significantly improved safety<br />
characteristics over conventional resistorized devices <strong>and</strong><br />
allow wellsite activities to continue uninterrupted while<br />
perforating.<br />
Features<br />
Does not use primary explosives<br />
Redundant electrical components for enhanced safety<br />
Ceramic firing capacitors for reliability<br />
Surface-mount circuit technology for ruggedness<br />
Thermally conductive semi-conductor bridge for stray<br />
power dissipation<br />
Metal housing for radio frequency shielding<br />
High-output explosive load <strong>and</strong> flyer plate assure reliable<br />
detonation transfer<br />
Specifications<br />
No-fire voltage level: 120 VDC<br />
Firing voltage: 155 to 190 VDC (nominal 175 VDC)<br />
Recommended firing method: “Dump firing.” Deliver<br />
250 VDC to the firing head<br />
Recommended firing polarity: positive or negative DC<br />
Requirements for radio silence waivers:<br />
– H<strong>and</strong>held RF transmitters (cell phones <strong>and</strong><br />
walkie-talkies) operation—minimum distance<br />
radius from explosive workplace = no minimum<br />
distance restriction<br />
– All other RF sources (l<strong>and</strong> or offshore, mobile or<br />
fixed) operation—minimum distance radius from<br />
explosive workplace = no minimum distance<br />
restriction<br />
– Offshore workboats (or other 1-MHz, 1,000 watt<br />
or above transmitters) operation—minimum<br />
distance radius from explosive workplace = no<br />
minimum distance restriction<br />
– Stray voltage measurement, electric welding<br />
operation, or electrical cathodic protection<br />
systems = operation acceptable if stray voltage is<br />
less than 2 V<br />
Bleed-off time with power removed: 5 sec<br />
SCB resistance: 2 ohms<br />
SCB no-fire power dissipation: 5 watts minimum<br />
Energetic materials:<br />
– Ignition pyrotechnic mix = 50 mg THKP<br />
– Transition column = 400 mg HMX<br />
– Output pellet = 500 mg HMX<br />
Temperature rating: 375°F for one hour<br />
UN shipping classification: 1.4S<br />
Top Fire RED® Style Detonator<br />
5-116 <strong>Perforating</strong> Solutions<br />
HAL11413
Dynamic Modeling<br />
Dynamic modeling is used to underst<strong>and</strong> perforation<br />
performance, tubing movement, shock loading, <strong>and</strong> wellbore<br />
pressure response during well intervention.<br />
PerfPro ® Process<br />
PerfPro ® Process– Predicting In-Situ Charge Performance<br />
<strong>Halliburton</strong>'s PerfPro® charge performance calculations for<br />
penetration are based on proprietary models derived from<br />
theoretical <strong>and</strong> experimental studies carried out at Jet<br />
Research Center (JRC), a <strong>Halliburton</strong> Company.<br />
API RP-19B defines the procedure for evaluating gun system<br />
performance at surface conditions in unstressed concrete<br />
targets. A fully loaded gun system is perforated in actual<br />
casing surrounded by concrete, <strong>and</strong> the target penetration,<br />
casing entrance hole, <strong>and</strong> burr height are recorded.<br />
<strong>Halliburton</strong>'s PerfPro program transforms<br />
API RP-19B Section I surface test data to downhole<br />
conditions by correcting for the formation compressive<br />
strength <strong>and</strong> effective stress. The associated downhole charge<br />
performance takes into account the gun positioning, casing<br />
grade, wellbore fluid density, <strong>and</strong> well condition.<br />
HAL15393<br />
PerfPro® Charge Performance Calculations<br />
The ability to underst<strong>and</strong> dynamic behavior is critical for<br />
<strong>Halliburton</strong> to deliver world-class solutions to its customers.<br />
Test<br />
Specimen<br />
Casing<br />
Gun<br />
Water<br />
Steel Form<br />
28-Day<br />
Concrete<br />
<strong>Perforating</strong> Solutions 5-117<br />
HAL15333<br />
API Section 1<br />
Concrete Target
The primary objective of the <strong>Halliburton</strong> PerfPro® process is<br />
to optimize gun selection <strong>and</strong> job execution to deliver the<br />
highest productivity index or lowest skin factor. Therefore,<br />
after charge performance values are calculated, the PerfPro<br />
program makes a productivity index <strong>and</strong> skin factor<br />
assessment. The PerfPro process accounts for skin factors due<br />
to perforation, drilling damage, partial penetration, non-<br />
Darcy flow, <strong>and</strong> well deviation. A fully three-dimensional<br />
CHARGE PERFORMANCE REPORT<br />
General Data<br />
Reservoir fluid type Oil Mid-Perforation Depth 3250.0 ft - TVD<br />
Borehole Diameter 12.25 in Reservoir Pressure 1464.0 psi<br />
Porosity 24.0 % Reservoir Temperature 112.0 °F<br />
Permeability 1191.0 md Completion Fluid Type Diesel<br />
Formation Compressive<br />
Strength<br />
3891.0 psi Completion Fluid Density 6.83 lb/gal<br />
Drilling Damage Radius 3.0 in Lithology S<strong>and</strong>stone<br />
Completion Data<br />
Casing Description 1<br />
Outer Diameter 9.63 in<br />
Inner Diameter 8.68 in<br />
Grade N-80<br />
Weight 47.0 lb/ft<br />
Perforator Information<br />
Charge Name 7"<br />
MILLENNIU<br />
M<br />
Gun 1 Gun 2 Gun 3<br />
4"<br />
MILLENNIU<br />
M<br />
4-1/2"<br />
MILLENNIU<br />
M<br />
Charge Type DP SDP SDP<br />
Charge Loading, gm 39.0 39.0 22.7<br />
Phasing, deg 45.0 60.0 30.0<br />
Shot Density, spg 12 5 12<br />
Gun Position Eccentered Eccentered Eccentered<br />
Avg Formation Penetration, in 40.68 43.22 23.78<br />
Avg Entrance Hole Dia*, in 0.36 0.29 0.28<br />
API 5th Edition Section I<br />
Data<br />
Total Target Penetration, in 43.3 52.0 26.8<br />
Entrance Hole Diameter, in 0.36 0.37 0.38<br />
PRODUCTIVITY REPORT<br />
(3D) flow model is utilized, as described by Ansah et al. 2001,<br />
to characterize the skin component due to perforation<br />
geometry. Input well parameters <strong>and</strong> calculated charge<br />
performance values are linked to an artificial neural network,<br />
trained by the 3D finite element model, to generate the<br />
perforation skin component. The productivity index <strong>and</strong><br />
total skin factor are corrected, utilizing analytical<br />
calculations for well inclination, partial penetration effect,<br />
non-Darcy flow, <strong>and</strong> drilling damage effects.<br />
Completion Data<br />
Reservoir Fluid Type Oil Well Deviation @ Perfs 56.2 deg<br />
Drainage Radius 1500.0 ft Net S<strong>and</strong> Thickness 27.0 ft<br />
Pseudo-Skin duetoWell<br />
Deviation<br />
-0.697 Perforated Total Length 27.0 ft<br />
Distance To Top Perf Interval 0.0 ft<br />
Skin due to Partial Penetration 0.0<br />
Reservoir Data<br />
Permeability 1191.0 md Reservoir Pressure 1464.0 psi<br />
Anisotropic Ratio, kV/kH 0.2 Reservoir Temperature 112.0 °F<br />
Formation Volume Factor 1.1 bbl/stb Porosity 24.0 %<br />
Formation Fluid Viscosity 4.36 cp API Gravity 32.6 °API<br />
Perforator Information<br />
Charge Name 7"<br />
MILLENNIU<br />
M<br />
Gun 1 Gun 2 Gun 3<br />
4"<br />
MILLENNIU<br />
M<br />
4-1/2"<br />
MILLENNIU<br />
M<br />
Gun Position Eccentered Eccentered Eccentered<br />
Shot Phasing, deg 45.0 60.0 30.0<br />
Shot Density, spf 12 5 12<br />
Avg Formation Penetration, in 40.68 43.22 23.78<br />
Avg Entrance Hole Dia, in 0.36 0.29 0.28<br />
Underbalance Condition, psi -350.0 -350.0 -500.0<br />
Productivity Analysis<br />
Total Skin Perforation Skin Productivity Index, STB/day/psi<br />
Gun No. 1 -0.666 0.031 7.2<br />
Gun No. 2 -0.158 0.539 6.682<br />
Gun No. 3 0.319 1.016 6.261<br />
5-118 <strong>Perforating</strong> Solutions
HAL15390<br />
HAL15389<br />
Total Pressure Drop (psi)<br />
1600<br />
1400<br />
1200<br />
1000<br />
800<br />
600<br />
400<br />
200<br />
7.2<br />
6.2<br />
Total Pressure Drop Vs Flow Rate<br />
0 0 2000 4000 6000 8000 10000<br />
Gun No.1 Gun No.2 Gun No.3<br />
PerfPro® Graph Example<br />
Pl <strong>and</strong> Total Skin Vs Gun<br />
Gun1 Gun 2<br />
Gun Number<br />
PI<br />
Total Skin<br />
Gun3<br />
PerfPro® Graph Example<br />
<strong>Perforating</strong> Solutions 5-119<br />
1.0<br />
0.0<br />
-1.0<br />
Total Skin
Near-Wellbore Stimulation <strong>and</strong> PulsFrac Software<br />
In many formations, the remaining<br />
reservoir pressure or underbalance is<br />
insufficient to effectively clean the<br />
perforations as suggested by King et al.<br />
(1985) <strong>and</strong> others. In other cases, where<br />
formation competence is questionable<br />
<strong>and</strong> the risk of sticking perforating<br />
assemblies is greater, sufficient<br />
underbalance pressure is not possible,<br />
aid in lowering treating pressures is<br />
needed, or bypassing near-wellbore<br />
damage is needed, then near-wellbore<br />
stimulation could be a possible<br />
perforating solution. To address the<br />
perforation damage in these cases,<br />
some (H<strong>and</strong>ren et al. 1993, Pettijohn<br />
<strong>and</strong> Couet, 1994; Snider <strong>and</strong> Oriold,<br />
1996) have suggested near-wellbore<br />
stimulation using extreme<br />
overbalanced (EOB) perforating <strong>and</strong><br />
propellant assisted perforating. Nearwellbore<br />
stimulation provides<br />
perforation breakdown in preparation<br />
for other stimulation methods, <strong>and</strong><br />
therefore, eliminates the need for<br />
conventional perforation breakdown<br />
methods.<br />
Near-wellbore stimulation can be<br />
achieved using energized fluids,<br />
propellants, or a combination of both,<br />
<strong>and</strong> all can be properly designed using<br />
the PulsFrac* dynamic pressure<br />
modeling software. The PulsFrac<br />
software allows a job simulation to be<br />
performed to determine anticipated<br />
peak pressures, injection rates,<br />
injection volumes, <strong>and</strong> theoretical<br />
fracture lengths.<br />
EOB - Energized Fluid Stimulation<br />
EOB techniques involve pressuring the<br />
wellbore with compressible gases above<br />
relatively small volumes of fluid. The<br />
gases have a high level of stored energy.<br />
Upon expansion at the instant of gun<br />
detonation, the gases are used to<br />
fracture the formation <strong>and</strong> divert fluids<br />
to all intervals. The high flow rate<br />
through relatively narrow fractures in<br />
the formation is believed to enhance<br />
near-well conductivity by extending the<br />
fractures past any drilling formation<br />
damage.<br />
Wellhead<br />
Isolation Tool<br />
Nitrogen<br />
300 ft of Fluid<br />
Radioactive<br />
Collar<br />
Packer<br />
Tubing<br />
Pressure-Operated<br />
Venture Firing Head<br />
Bauxite<br />
Proppant<br />
Carrier<br />
VannGun ®<br />
Assembly<br />
5-120 <strong>Perforating</strong> Solutions<br />
HAL15314<br />
Typical Extreme<br />
Overbalanced (EOB)<br />
<strong>Perforating</strong> Assembly
Building upon the success of EOB<br />
perforating, Marathon Oil Company<br />
incorporated proppant carriers into the<br />
perforation assembly to introduce<br />
proppants into the flow path as the gun<br />
detonates. The POWR*PERF process,<br />
patented by Marathon Oil Company,<br />
further enhances productivity by<br />
scouring the perforations to leave some<br />
residual conductivity on the fracture<br />
plane. Most EOB perforating jobs are<br />
designed with a minimum pressure<br />
level of 1.4 psi/ft of true vertical depth.<br />
For optimum results, it is suggested to<br />
utilize the highest possible pressure<br />
level without compromising wellbore<br />
integrity or operation safety.<br />
Propellant Stimulation<br />
Propellant stimulation can be provided<br />
during the perforating event with<br />
propellant-assisted perforating.<br />
Propellant-assisted perforating using<br />
the StimGun assembly, patented by<br />
Marathon Oil Company, combines<br />
solid propellant technology with<br />
conventional perforating. The StimGun<br />
assembly may be utilized for either EOB<br />
or conventional underbalanced<br />
perforating. The hardware utilized for<br />
either system remains the same aside<br />
from added protection by using<br />
centralizer rings to protect the brittle<br />
propellant material. The propellant<br />
sleeve in the StimGun assembly simply<br />
slides over the perforation scalloped<br />
carrier <strong>and</strong> is held in position on the<br />
gun with the centralizer rings.<br />
The propellant material is potassium<br />
perchlorate, an oxidizer that burns<br />
rapidly, creating carbon dioxide gas. As<br />
the shaped charges detonate, the<br />
propellant is ignited by extreme heat<br />
from the gun system. As it burns, the<br />
propellant generates carbon dioxide gas<br />
at high peak pressures typically well<br />
above the formation fracture gradient.<br />
The StimGun assembly is an effective<br />
method for mild stimulation (fractures<br />
on order of 2 to 9 ft) for treating nearwellbore<br />
problems.<br />
Propellant stimulation can also occur<br />
using solid propellant conveyed in<br />
protective carriers. This type of<br />
propellant can virtually be unlimited in<br />
length by simply interconnecting the<br />
carriers to place across existing<br />
perforations, slotted liner, or in<br />
openhole. The propellant is ignited<br />
using a sealed ignition system, <strong>and</strong><br />
similar to the StimGun assembly once<br />
the propellant is ignited it will generate<br />
carbon dioxide at high peak pressure,<br />
allowing for adequate stimulation of<br />
the desired formation interval. As with<br />
all near-wellbore stimulation<br />
techniques, PulsFrac software aids in<br />
proper job design <strong>and</strong> provides<br />
estimated peak pressures, injection<br />
rates, <strong>and</strong> volumes to ensure successful<br />
propellant stimulation.<br />
RA Marker<br />
Safety Joint<br />
Retrievable<br />
Packer<br />
Fill Disk<br />
Firing Head<br />
Centralizer<br />
Fast Gauge<br />
Recorder<br />
<strong>Perforating</strong> Solutions 5-121<br />
HAL15977<br />
StimGun Assembly
Near-Wellbore Stimulation<br />
Increasing conductivity past near-wellbore damage is critical<br />
in maximizing a well’s producibility. <strong>Halliburton</strong> provides<br />
multiple solutions suitable for various stimulation scenarios<br />
depending upon the well's restriction, completion methods,<br />
<strong>and</strong> reservoir characteristics.<br />
StimGun* Assembly<br />
The StimGun assembly is a process that combines<br />
perforating <strong>and</strong> perforation breakdown with propellant in<br />
a single tool <strong>and</strong> operation. The StimGun assembly has a<br />
propellant sleeve over a conventional <strong>Halliburton</strong><br />
VannGun® perforating gun assembly. When the guns are<br />
detonated, the propellant sleeve is ignited, instantly<br />
producing a burst of high-pressure CO 2 gas. This gas enters<br />
the perforations, breaks through any damage around the<br />
perforation tunnel, <strong>and</strong> creates short fractures near the<br />
wellbore. As the gas pressure in the wellbore dissipates, the<br />
gas in the formation surges back into the wellbore carrying<br />
with it damaging fines. The StimGun assembly has been<br />
used with great success in conventional underbalanced<br />
perforating to obtain the benefits of both extreme<br />
overbalance from propellants <strong>and</strong> the surging effect from<br />
maximum underbalance.<br />
Features<br />
Improved production or injectivity with greater<br />
uniformity in the perforation breakdown<br />
Improved connectivity to the undamaged reservoir matrix<br />
by extending fractures past damage induced by either<br />
drilling or completion practices<br />
Improved conventional underbalanced perforating by<br />
combining benefits of extreme overbalance in one<br />
operation<br />
Stimulation of near-wellbore on zones that cannot be<br />
treated conventionally with acid or hydraulic fracturing<br />
due to undesirable production from nearby gas cap or<br />
water contact<br />
Excellent pre-hydraulic fracture treatment assists in<br />
keeping perforations open <strong>and</strong> minimizes tortuosity<br />
effects, resulting in lower breakdown pressures <strong>and</strong><br />
horsepower requirements on location<br />
*StimGun is a trademark of Marathon Oil Company <strong>and</strong> is licensed to<br />
<strong>Halliburton</strong> by Marathon. StimGun Assembly<br />
Radioactive<br />
Marker<br />
Safety Joint<br />
Retrievable<br />
Packer<br />
Fill Disk<br />
Firing Head<br />
Centralizer<br />
Fast Gauge<br />
Recorder<br />
<strong>Perforating</strong> Solutions 5-127<br />
HAL15417
Operation<br />
The StimGun assembly consists of a cylindrical sleeve of<br />
gas-generating propellant-potassium perchlorate that slides<br />
in place over the outside of a conventional hollow steel<br />
carrier perforating gun. The StimGun assembly can be<br />
conveyed on either wireline, coiled tubing, or in a<br />
conventional perforation configuration. StimGun sleeves are<br />
similar to PVC pipe <strong>and</strong> must be protected <strong>and</strong> positioned on<br />
the gun with an oversized retaining collar that is secured to<br />
the gun scallop. Additional sleeve protection is achieved<br />
through centralization of the gun sections at the t<strong>and</strong>ems.<br />
The StimGun tool can be run on <strong>Halliburton</strong> tubingconveyed<br />
or wireline equipment.<br />
5-128 <strong>Perforating</strong> Solutions<br />
HAL5941
Gun Size<br />
in.<br />
Sleeve SAP No.<br />
2 1/2 58179<br />
2 3/4 58190<br />
3 1/8 58193<br />
3 3/8 58195<br />
4 58196<br />
4 5/8 57514<br />
5 1/8 101240496<br />
5 3/4 215347<br />
7 58159<br />
StimGun Assembly Specifications<br />
Sleeve OD<br />
in. (mm)<br />
3.11<br />
(78.99)<br />
3.36<br />
(85.34)<br />
3.72<br />
(94.48)<br />
4.02<br />
(102.10)<br />
4.71<br />
(119.63)<br />
5.21<br />
(132.33)<br />
5.81<br />
(147.63)<br />
6.45<br />
(163.83)<br />
7.88<br />
(200.15)<br />
Sleeve ID<br />
in. (mm)<br />
2.50<br />
(63.50)<br />
2.75<br />
(69.85)<br />
3.21<br />
(81.53)<br />
3.38<br />
(85.85)<br />
4.05<br />
(102.87)<br />
4.72<br />
(119.88)<br />
5.175<br />
(131.44)<br />
5.75<br />
(146.05)<br />
7.09<br />
(180.08)<br />
Minimum<br />
Centralizer OD*<br />
in. (mm)<br />
3.50<br />
(88.90)<br />
3.76<br />
(95.50)<br />
4.13<br />
(104.90)<br />
4.40<br />
(111.76)<br />
5.09<br />
(129.28)<br />
5.63<br />
(143.00)<br />
6.18<br />
(156.97)<br />
6.95<br />
(176.53)<br />
8.25<br />
(209.55)<br />
Propellant Mass**<br />
lb/ft (kg/m)<br />
<strong>Perforating</strong> Solutions 5-129<br />
2.01<br />
(2.99)<br />
2.01<br />
(2.99)<br />
2.33<br />
(3.46)<br />
2.67<br />
(3.98)<br />
3.68<br />
(5.47)<br />
3.33<br />
(4.96)<br />
3.99<br />
(5.94)<br />
4.68<br />
(6.97)<br />
7.01<br />
(10.43)<br />
StimGun sleeves are manufactured in st<strong>and</strong>ard 3 ft (0.91 m) lengths <strong>and</strong> are rated for a service temperature of 350°F (177°C). The<br />
sleeves are non-reactive to most commonly used oilfield fluids, including acids.<br />
*The StimGun sleeve is an oxidizer that is bonded with a resin or plastic, making it quite brittle; therefore, it is required that the perforating<br />
gun be centralized to this minimum OD to provide protection when the assembly is in the wellbore.<br />
**CO 2 gas generated from a propellant burn is estimated at 7.06 scf per kg of material at st<strong>and</strong>ard conditions.<br />
SAP No.<br />
Gun Size<br />
in.<br />
101233588 2 1/2<br />
101233598 2 3/4<br />
101233215 3 1/8<br />
101240387 3 3/8 12 spf<br />
101222271 3 3/8<br />
101233163 4<br />
101227396 4 5/8<br />
101239368 5 1/8<br />
101303748 5 3/4<br />
101292913 7<br />
Retaining Collar Assembly Specifications<br />
OD<br />
in. (mm)<br />
3.38<br />
(85.85)<br />
3.63<br />
(92.20)<br />
4.02<br />
(102.10)<br />
4.27<br />
(108.45)<br />
4.27<br />
(108.45)<br />
4.96<br />
(125.98)<br />
5.50<br />
(139.70)<br />
6.05<br />
(153.67)<br />
6.70<br />
(170.18)<br />
8.15<br />
(207.01)<br />
ID<br />
in. (mm)<br />
2.56<br />
(65.02)<br />
2.81<br />
(71.37)<br />
3.18<br />
(80.77)<br />
3.43<br />
(87.12)<br />
3.43<br />
(87.12)<br />
4.06<br />
(103.12)<br />
4.69<br />
(119.12)<br />
5.19<br />
(131.82)<br />
5.82<br />
(147.82)<br />
7.07<br />
(179.57)<br />
Sleeve OD<br />
in. (mm)<br />
3.11<br />
(78.99)<br />
3.36<br />
(85.34)<br />
3.72<br />
(94.48)<br />
4.02<br />
(102.10)<br />
4.02<br />
(102.10)<br />
4.71<br />
(119.63)<br />
5.21<br />
(132.33)<br />
5.81<br />
(147.32)<br />
6.45<br />
(163.83)<br />
7.88<br />
(200.15)<br />
Minimum<br />
Centralizer OD<br />
in. (mm)<br />
3.51<br />
(89.15)<br />
3.76<br />
(95.50)<br />
4.13<br />
(104.90)<br />
4.40<br />
(111.76)<br />
4.40<br />
(111.76)<br />
5.09<br />
(129.28)<br />
5.63<br />
(143.00)<br />
These ratings are guidelines only. For more information, consult your local <strong>Halliburton</strong> representative.<br />
6.18<br />
(156.97)<br />
6.95<br />
(176.53)<br />
8.25<br />
(209.55)<br />
Flow Area through Collar<br />
in. 2 (mm 2 )<br />
1.10<br />
(709.67)<br />
1.15<br />
(741.93)<br />
1.21<br />
(780.64)<br />
1.71<br />
(1103.22)<br />
1.71<br />
(1103.22)<br />
2.00<br />
(1290.32)<br />
2.00<br />
(1290.32)<br />
2.21<br />
(1425.80)<br />
2.70<br />
(1741.93)<br />
3.75<br />
(2419.35)
Propellent Stimulation Tool Assembly<br />
The stimulation tool assembly is a process that uses the same<br />
solid propellant technology employed by the StimGun<br />
assembly to stimulate existing perforations, slotted liners, or<br />
openhole sections when it is not desirable to add<br />
perforations. The stimulation assembly is assembled with<br />
propellant <strong>and</strong> st<strong>and</strong>ard detonating cord to provide the<br />
ignition system. When the detonating cord is ignited, the<br />
solid propellant breaks up into many smaller pieces, allowing<br />
it to burn very rapidly <strong>and</strong> producing CO 2 gas. This gas<br />
enters the perforations, breaking through any damage<br />
around the perforation tunnel, creating short fractures near<br />
the wellbore. As the gas pressure in the wellbore dissipates,<br />
the gas in the formation surges back into the wellbore,<br />
carrying with it damaging fines. Stimulation assembly jobs<br />
are designed using <strong>Halliburton</strong>’s PulsFrac simulator, which<br />
assists in achieving consistent results without compromising<br />
safety or wellbore integrity.<br />
Operation<br />
The stimulation assembly consists of a solid stick of gasgenerating<br />
propellant-potassium perchlorate with<br />
detonating cord run through it. The assembly can be<br />
conveyed on either wireline, coiled tubing, or threaded pipe.<br />
St<strong>and</strong>ard perforating safety, arming, <strong>and</strong> firing procedures<br />
are used. The industry st<strong>and</strong>ard detonating cord provides<br />
consistent, reliable, <strong>and</strong> instantaneous ignition over the<br />
entire length of the stimulation assembly.<br />
When deployed on coiled tubing or threaded pipe, the<br />
stimulation assembly is run inside a vented hollow steel<br />
carrier.<br />
Stimulation Assembly<br />
5-130 <strong>Perforating</strong> Solutions<br />
HAL22575
Features<br />
Improved production or injectivity with greater<br />
uniformity in the perforation breakdown<br />
Improved connectivity to the undamaged reservoir<br />
matrix by extending fractures past damage induced by<br />
either drilling or completion practices<br />
Stimulation of near-wellbore on zones that cannot be<br />
treated conventionally with acid or hydraulic fracturing<br />
due to undesirable production from nearby gas cap or<br />
water contact<br />
SAP No.<br />
Tool Size<br />
in.<br />
Upper<br />
Thread<br />
Size <strong>and</strong><br />
Type<br />
2 7/8 Gun<br />
101566827 2 7/8<br />
Pin<br />
1<br />
Based on control line collapse rating<br />
2<br />
2 7/8 gun box at top sub<br />
Lower<br />
Thread<br />
Size <strong>and</strong><br />
Type<br />
2 7/8 Gun<br />
Box<br />
Stimulation Tool Assembly Specifications<br />
Overall<br />
Length<br />
ft (m)<br />
26.25<br />
(8.0)<br />
Makeup<br />
Length<br />
ft (m)<br />
25.98<br />
(7.92)<br />
Excellent pre-hydraulic fracture treatment assists in<br />
keeping perforations open <strong>and</strong> minimizes tortuosity<br />
effects resulting in lower breakdown pressures <strong>and</strong><br />
horsepower requirements on location<br />
Selective stimulation of long openhole horizontal<br />
sections<br />
This assembly is currently available in 2 7/8 OD ported<br />
carriers. Contact TCP technology for more information.<br />
Maximum<br />
OD<br />
in. (mm)<br />
Temperature<br />
Rating 1<br />
°F (°C)<br />
Pressure<br />
Rating 1<br />
psi (bar)<br />
Tensile<br />
Rating 2<br />
lb (kg)<br />
Redressable<br />
<strong>Perforating</strong> Solutions 5-131<br />
2.88<br />
(73.2)<br />
300<br />
(149)<br />
8500<br />
(578)<br />
110,800<br />
(50 250)<br />
Yes<br />
Weight<br />
(No<br />
Explosives)<br />
lb (kg)<br />
249<br />
(113)
POWR*PERF SM* Perforation/Stimulation Process<br />
POWR*PERF SM perforation/<br />
stimulation process is a completion<br />
process that uses proven extreme<br />
overbalance perforating techniques.<br />
This method is coupled with the<br />
release of an erosive agent at the<br />
moment of VannGun® detonation to<br />
clean <strong>and</strong> scour near-wellbore damage<br />
<strong>and</strong> enhance conductivity of fractures<br />
created by extreme overbalance<br />
perforating.<br />
Features<br />
Overcomes skin damage in low<br />
pressure, high permeability wells<br />
Can be a useful pre-frac<br />
evaluation tool<br />
Applicable to both new wells <strong>and</strong><br />
wells with nearby water or gas<br />
Compatible with all casing sizes<br />
<strong>and</strong> tubulars<br />
Operation<br />
The POWR*PERF tool is run as a<br />
normal part of the completion<br />
assembly. A non-damaging fluid is<br />
added to the tubing to serve as a<br />
medium for carrying the bauxite<br />
into the formation. After the assembly<br />
has been positioned across the<br />
producing zone, the tubing is<br />
energized with nitrogen gas to create a<br />
pressure gradient of no less than<br />
1.4 psi/ft (31 bar/m). A model KV-II<br />
firing head, which has been pre-set to<br />
function at the desired bottomhole<br />
pressure, detonates the VannGun<br />
assembly <strong>and</strong> opens flow ports to<br />
allow the fluid <strong>and</strong> nitrogen to rush<br />
toward the formation.<br />
The fluid “spear” is driven ahead of<br />
the exp<strong>and</strong>ing nitrogen gas into the<br />
formation at velocities that can exceed<br />
140 bbl/min. The bauxite material is<br />
ejected into the fluid stream at the<br />
moment of detonation by specially<br />
designed shaped charges. The<br />
combination of fluid <strong>and</strong> bauxite<br />
serves to fracture, erode, <strong>and</strong> scour all<br />
of the perforations, <strong>and</strong> to further<br />
enhance the fractures created by<br />
extreme overbalance perforating.<br />
*POWR*PERF is a service mark/trademark of<br />
Marathon Oil Company <strong>and</strong> licensed by<br />
<strong>Halliburton</strong>.<br />
Retrievable<br />
Packer<br />
KV-II Firing<br />
Head<br />
Proppant<br />
Carrier<br />
®<br />
VannGun<br />
Assembly<br />
POWR*PERF SM<br />
Perforation/Stimulation Process<br />
5-132 <strong>Perforating</strong> Solutions<br />
HAL15314
PerfStim* Process<br />
The PerfStim process uses an extreme overbalanced<br />
condition to simultaneously perforate <strong>and</strong> stimulate a well.<br />
The process not only produces cleaner perforations in lowpressure<br />
formations, it also initiates fractures in the<br />
formation, reducing stimulation costs.<br />
Features<br />
Gets production flowing quickly<br />
Saves rig time<br />
Helps develop negative skin factors<br />
Gives an early evaluation of a well’s potential<br />
Uses less horsepower than full scale stimulations<br />
Operation<br />
In the PerfStim process, an extreme overbalanced<br />
condition is created—pressure gradients of at least<br />
1.4 psi/ft (31 bar/m).<br />
When the perforating gun fires, the pressure drives a fluid<br />
“spear” into the perforation at velocities exceeding<br />
3,000 ft/sec (900 m/sec) <strong>and</strong> at rates that can exceed<br />
140 bbl/min. Crushed zone damage is removed <strong>and</strong> small<br />
fractures are created—improving initial production <strong>and</strong><br />
treatment results.<br />
*The PerfStim process is licensed to <strong>Halliburton</strong> by Oryx Energy Company.<br />
PerfStim is a trademark of Oryx Energy Company.<br />
Packer<br />
Firing Head<br />
®<br />
VannGun<br />
Assembly<br />
<strong>Perforating</strong> Solutions 5-133<br />
HAL15387<br />
<strong>Halliburton</strong>’s VannSystem® toolstring is used in typical<br />
PerfStim procedures. The tubing conveyed system helps to<br />
allow for the highest possible bottomhole pressures. A small<br />
volume (usually no more than a 300-ft column) of nondamaging<br />
fluid is placed above the gun, then pressured with<br />
nitrogen. If needed, a liquid can be bullheaded on top of the<br />
nitrogen column. The VannGun® perforating assembly can<br />
remain attached to the toolstring or dropped into the rathole<br />
after the guns have been fired.
Oriented <strong>Perforating</strong><br />
The benefits of s<strong>and</strong> prevention or<br />
improved stimulation performance can<br />
be enjoyed using any of <strong>Halliburton</strong>'s<br />
leading oriented perforation<br />
technologies. <strong>Halliburton</strong> oriented<br />
perforating solutions can be deployed<br />
using a wide range of conveyance<br />
methods providing reliable world-class<br />
results.<br />
G-Force ® Precision Oriented<br />
<strong>Perforating</strong> System<br />
Historically, oriented perforating was<br />
attempted via external orienting<br />
devices <strong>and</strong> weights (external to the<br />
gun <strong>and</strong> exposed to the casing<br />
environment). In the externally<br />
oriented systems, there is added<br />
friction created by the guns moving<br />
axially down the casing wall, which<br />
can significantly work against the<br />
orienting mechanism. In addition,<br />
doglegs <strong>and</strong> other discontinuities<br />
during the deployment can cause loss<br />
of orientation.<br />
It was conceived that if the rotating<br />
device could be taken inside the<br />
protective environment of the carrier,<br />
adverse factors that can significantly<br />
decrease the ability to orient the guns in<br />
a desired direction could be overcome,<br />
if not completely eliminated.<br />
<strong>Halliburton</strong>'s G-Force® system is<br />
comprised of an internal orienting<br />
charge tube assembly <strong>and</strong> gun carrier,<br />
which allows perforating in any<br />
direction irrespective of the gun's<br />
position relative to the casing.<br />
Features<br />
Able to go through restrictions not<br />
possible with older systems<br />
Since the orienting mechanism of the<br />
internal orienting system is<br />
contained within the gun carrier, the<br />
fundamental orienting design is<br />
unaffected by potential restrictions in<br />
the completion string<br />
Able to run through tubing <strong>and</strong><br />
orient in casing<br />
No need for fin t<strong>and</strong>ems, eccentric<br />
t<strong>and</strong>ems, <strong>and</strong> swivel subs<br />
Increased orientation accuracy: the<br />
operating range will be for wells of 25°<br />
deviation <strong>and</strong> greater. For deviated<br />
wells, the accuracy range is ± 5°<br />
Compatible with live well<br />
intervention systems such as the<br />
AutoLatch connector, ratchet<br />
connector, <strong>and</strong> the modular gun<br />
system<br />
Gun assemblies can be centralized in<br />
the casing<br />
Can be deployed on coiled tubing,<br />
wireline, slickline, or jointed pipe<br />
No external weight bars required<br />
means no gaps between loaded<br />
sections <strong>and</strong> no lost shots<br />
G-Force® System<br />
5-134 <strong>Perforating</strong> Solutions<br />
HAL12019
SAP No.<br />
101300078<br />
SAP No.<br />
101305067<br />
SAP No.<br />
Thread Size <strong>and</strong><br />
Type<br />
in. (mm)<br />
2 7/8 (73.03)<br />
6P Acme<br />
Thread Size <strong>and</strong><br />
Type<br />
in. (mm)<br />
4.00 6P Acme<br />
(101.60 Acme)<br />
Gun OD<br />
in.<br />
Gun OD<br />
in. (mm)<br />
3.375<br />
(85.73)<br />
SAP No.<br />
101300078<br />
Gun OD<br />
in. (mm)<br />
4.625<br />
(117.48)<br />
SAP No.<br />
101305067<br />
Length ft<br />
3.375-in. G-Force ® System Specifications<br />
Length<br />
ft (m)<br />
22<br />
(6.7)<br />
Tensile Load<br />
lb (kg)<br />
238,000<br />
(107 954)<br />
Maximum<br />
Shot<br />
Density<br />
4 spf<br />
(13 spm)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
25,000<br />
(1725)<br />
Shot<br />
Phasing<br />
Perforation<br />
Planes<br />
180° 2<br />
T<strong>and</strong>em Tensile Load<br />
lb (kg)<br />
355,000<br />
(161 025)<br />
Vertical<br />
Shot<br />
Spacing<br />
in. (mm)<br />
2.8<br />
(71.12)<br />
4.625-in. G-Force ® System Specifications<br />
Length<br />
ft (m)<br />
22<br />
(6.7)<br />
Tensile Load<br />
lb (kg)<br />
403,000<br />
(182 783)<br />
Maximum<br />
Shot<br />
Density<br />
4 spf<br />
(13 spm)<br />
Collapse<br />
Pressure<br />
psi (bar)<br />
20,000<br />
(1378.95)<br />
Shot<br />
Phasing<br />
Perforation<br />
Planes<br />
180° 2<br />
T<strong>and</strong>em Tensile Load<br />
lb (kg)<br />
563,000<br />
(255 372)<br />
G-Force ® System Specifications<br />
Maximum<br />
Shot Density<br />
Shot<br />
Phasing<br />
Perforation<br />
Planes<br />
Maximum<br />
Shots per<br />
Gun<br />
Vertical<br />
Shot<br />
Spacing<br />
in. (mm)<br />
2.8<br />
(71.12)<br />
Survival Test<br />
Medium<br />
Maximum Diameter<br />
after Detonation<br />
in. (mm)<br />
3.42<br />
(86.87)<br />
Distance from Top<br />
End of Gun to<br />
First Shot<br />
in. (mm)<br />
8.50<br />
(215.90)<br />
<strong>Perforating</strong> Solutions 5-135<br />
Fluid<br />
Survival Test<br />
Medium<br />
Fluid<br />
Distance<br />
to First<br />
Shot in.<br />
Maximum Diameter<br />
after Detonation<br />
in. (mm)<br />
4.69<br />
(118.87)<br />
Charge<br />
Distance from Top<br />
End of Gun to<br />
First Shot<br />
in. (mm)<br />
8.50<br />
(215.90)<br />
101450833 4 5/8 16.00 4 spf 10°-350° 2 52 7.94 101466192 - 39g DP HMX<br />
101498446 4 5/8 22.00 4 spf 0°-180° 2 76 9.94 101210636 - 39g Millennium<br />
101435773 4 5/8 22.00 4 spf 0° 1 75 8.60 101210636 - 39g Millennium<br />
101426443 4 5/8 22.00 4 spf 10°-350° 2 75 8.60 101210636 - 39g Millennium<br />
101390900 4 5/8 22.00 4 spf 0°-180° 2 75 8.60 101210636 - 39g Millennium<br />
101294752 3 3/8 4.83 4 spf 10°-350° 2 14 9.50 101366678 - 21g Millennium<br />
101640605 3 3/8 4.83 4 spf 180° 1 14 9.50 101366678 - 21g Millennium<br />
101515354 3 3/8 22.00 4 spf 0°-180° 2 72 9.25 101371884 - 25g Super DP<br />
101407434 3 3/8 22.00 4 spf 0°-180° 2 72 9.25 101366678 - 21g Millennium<br />
101406739 3 3/8 22.00 4 spf 0° 1 72 9.25 101366678 - 21g Millennium<br />
101295030 3 3/8 2.00 4 spf 0° OR 180° 1 or 2 2 10.00 101366678 - 21g Millennium<br />
101630791 2 7/8 16.00 4 spf 10°-350° 2 56 7.74 101571815 - 11.1g G-Force ® HMX<br />
101621606 2 7/8 4.00 4 spf 0° OR 180° 1 or 2 12 7.62 101571815 - 11.1g G-Force HMX<br />
101600677 2 7/8 22.00 4 spf 10°-350° 2 78 7.62 101571815 - 11.1g G-Force HMX<br />
101563379 2 7/8 22.00 4 spf 0° OR 180° 1 or 2 78 7.62 101571815 - 11.1g G-Force HMX
Oriented <strong>Perforating</strong> with Modular Guns<br />
There are several methods available for orienting perforating<br />
guns in horizontal <strong>and</strong> highly deviated wells, such as the<br />
G-Force® system. In vertical wells it can be more difficult to<br />
orient perforations in a particular direction. One proven<br />
method is the oriented Modular Gun System.<br />
To accomplish this, a st<strong>and</strong>ard auto-J gun hanger is used in<br />
conjunction with specially modified skirts <strong>and</strong> stingers for<br />
the modular guns. The stingers are made with locating lugs,<br />
<strong>and</strong> the skirts are modified to locate on the lugs.<br />
The gun hanger is run in the well <strong>and</strong> set on wireline using<br />
normal procedures. A gyro steering tool is then run to<br />
determine the direction of the locating lug on the gun hanger<br />
stinger. The skirts <strong>and</strong> stingers on the remaining gun<br />
modules are then adjusted accordingly so that when they are<br />
l<strong>and</strong>ed, the shots will be oriented to the desired direction.<br />
This system has been used successfully in st<strong>and</strong>ard<br />
applications when perforating for production, <strong>and</strong> in special<br />
applications such as shooting from a relief well into a well<br />
that is blowing out.<br />
Stinger<br />
Gun Hanger<br />
with Modifications<br />
Modular Gun<br />
with Modifications<br />
Modified Skirt<br />
Modified Stinger<br />
Modified Skirt<br />
<strong>and</strong> Stinger<br />
Assembly<br />
5-136 <strong>Perforating</strong> Solutions<br />
HAL24404<br />
Lug<br />
HAL24407<br />
HAL24406<br />
HAL24405<br />
HAL24403
Finned Orienting T<strong>and</strong>em<br />
As perforating guns are run into the well, <strong>and</strong> transition from<br />
a vertical to deviated position occurs, the fin will orient to<br />
the high side of the wellbore. The finned t<strong>and</strong>em works on<br />
the principle of gravity whereby the weight of the perforating<br />
guns rotates towards the lowest side of the wellbore <strong>and</strong> is<br />
aided by the additional st<strong>and</strong>off from the casing wall created<br />
by the connected fin.<br />
Features<br />
Built with an adjustable ring, which makes it possible to<br />
orient the shots in the casing to a predetermined<br />
direction<br />
Tensile strength of finned t<strong>and</strong>em equivalent to the<br />
st<strong>and</strong>ard gun connectors<br />
Available for most gun sizes<br />
Cost effective perforation orientation solution<br />
Finned Orienting T<strong>and</strong>em<br />
<strong>Perforating</strong> Solutions 5-137<br />
HAL24409
Eccentric Orienting T<strong>and</strong>em<br />
For several years, <strong>Halliburton</strong> successfully ran oriented<br />
perforating jobs using a fin welded to a gun connection every<br />
30 ft in conjunction with swivel assemblies.<br />
Now, a second method for orienting perforations referred<br />
to as eccentric subs has been developed. The eccentric sub<br />
is run in place of the finned t<strong>and</strong>em still in conjunction<br />
with a swivel assembly.<br />
The eccentric t<strong>and</strong>em works on the same principle as the<br />
fins. As the guns are run into the well, <strong>and</strong> transition from a<br />
vertical to deviated position occurs, the natural tendency is<br />
for the fin to orient to the high side of the wellbore. The<br />
eccentric t<strong>and</strong>em works on the same principle. The eccentric<br />
t<strong>and</strong>ems allows for a greater degree of accuracy with an<br />
overall smaller profile.<br />
Features<br />
Eccentric subs allow perforating guns to be oriented in<br />
situations where the fin system is not ideal due to restrictions<br />
in the casing, fishing concerns, welding concerns, etc. Several<br />
tests <strong>and</strong> wells have been perforated using this new technique<br />
in the North Sea area <strong>and</strong> the Gulf of Mexico.<br />
Built with an adjustable ring, which makes it possible to<br />
orient the shots in the casing to a predetermined direction<br />
Tensile strength of the eccentric sub equivalent to the<br />
st<strong>and</strong>ard gun connectors<br />
Available for most gun sizes<br />
Eliminates the use of welded fins on the connectors<br />
Eccentric Orienting T<strong>and</strong>em<br />
5-138 <strong>Perforating</strong> Solutions<br />
HAL15456
Special Applications<br />
Modular Gun System<br />
Through a special arrangement of perforating equipment,<br />
<strong>Halliburton</strong>’s modular gun system permits the optimum<br />
number of guns to be removed via slickline or<br />
electric line so larger intervals can be perforated<br />
simultaneously. In fact, the modular gun system is so<br />
innovative, <strong>Halliburton</strong> has patented* this unique system,<br />
proving once again our commitment to bring the latest<br />
technology to the wellsite.<br />
The modular gun system is run by <strong>Halliburton</strong> perforating<br />
specialists who know the equipment, know your well, <strong>and</strong><br />
know the best techniques to fit your particular application.<br />
And of course, the modular gun system is backed by<br />
<strong>Halliburton</strong>’s worldwide network of technical support,<br />
reliable equipment, <strong>and</strong> innovative performance—all of<br />
which are ready to go wherever <strong>and</strong> whenever needed.<br />
Features<br />
Ideal for monobore completions<br />
With the modular gun system, you are able to stack an<br />
optimum number of guns downhole for perforating the<br />
maximum interval<br />
Several features make the modular gun system your best<br />
choice for perforating under a wide range of conditions<br />
– The guns are retrievable or can be left at<br />
the bottom of the hole<br />
– The system allows perforating in either<br />
underbalanced or overbalanced<br />
conditions over the entire interval<br />
– Wide range of gun sizes (2- to 7-in. OD)<br />
permits deployment over a wide range of<br />
casing, from 3 1/2 to 9 5/8 in.<br />
No rig is required—the system is ideal for rigless<br />
completions<br />
The modular gun system can be deployed via coiled<br />
tubing, electric wireline, or slickline, as well as with<br />
conventional tubing or drillstring<br />
The modular gun system allows a zone to be perforated<br />
<strong>and</strong> tested with no downhole restrictions below or above<br />
the packer<br />
Proven VannSystem® guns <strong>and</strong> firing heads are used in the<br />
modular gun system<br />
<strong>Wireline</strong><br />
Running Tool<br />
Stinger Skirt<br />
Stinger<br />
Modular Gun System Configuration<br />
*US Patent Number 5,366,014<br />
Retrievable<br />
Firing Head<br />
(<strong>Wireline</strong><br />
Conveyed)<br />
Centralizer<br />
Auto-Release<br />
Gun Hanger<br />
<strong>Perforating</strong> Solutions 5-139<br />
HAL6093
The Modular Gun System Process<br />
The modular gun system allows operators to deploy multiple<br />
gun sections to perforate long intervals. The gun modules are<br />
deployed downhole individually <strong>and</strong> stacked on each other at<br />
the perforating zone until the appropriate length is achieved<br />
with the lowermost gun module being supported by the gun<br />
hanger. This method avoids any gun length restrictions<br />
caused by the lubricator. The auto-release gun hanger<br />
positions the perforating assembly <strong>and</strong> allows it to remain<br />
adjacent to the desired interval. The guns are fired, via a<br />
pressure-actuated firing head, <strong>and</strong> are then, automatically<br />
released to the bottom of the hole where they can later be<br />
retrieved or left in the hole.<br />
The modular gun system is ideal for use in wells with rathole<br />
length restrictions <strong>and</strong> rigless completions.<br />
Rathole Length Restriction<br />
In this application, insufficient rathole length causes the<br />
uppermost gun modules to remain adjacent to the<br />
perforated interval after they are fired—where they may<br />
interfere with production from the well. The modular gun<br />
system allows the guns to be retrieved in sections without<br />
having to kill the well.<br />
Rigless Completion<br />
On wells where the completions are installed with wireline or<br />
coiled tubing, the modular gun system is the preferred<br />
method for perforating. No rig is required, saving both time<br />
<strong>and</strong> money.<br />
5-140 <strong>Perforating</strong> Solutions<br />
HAL15458<br />
HAL15457<br />
Stinger Assembly<br />
Skirt Assembly
Select Fire Systems<br />
The Select Fire system offers flexibility in perforating,<br />
testing, <strong>and</strong> evaluating multiple zones in one trip. The<br />
Select Fire system saves rig time <strong>and</strong> tool charges to help<br />
multiply profits.<br />
Features<br />
<strong>Perforating</strong> <strong>and</strong> testing several individual zones — one<br />
at a time<br />
Selecting the order zones are perforated<br />
Customizing gun configurations for various applications<br />
Available for all VannGun® assemblies 2-in. <strong>and</strong> larger<br />
Helps develop essential information about the reservoir —<br />
potentially saving hundreds of thous<strong>and</strong>s of dollars<br />
Saves rig time <strong>and</strong> tool charges to help multiply profits<br />
HAL10537<br />
A<br />
I<br />
R<br />
C<br />
H<br />
A<br />
M<br />
B<br />
E<br />
R<br />
P<br />
R<br />
E<br />
S<br />
S<br />
U<br />
R<br />
E<br />
Before Firing<br />
Select Fire Sub Operation<br />
When gun #1 fires, the<br />
explosives train is continued<br />
to the Select Fire Sub, which fires<br />
a shaped charge downward.<br />
Pressure may now enter into<br />
the air chamber. (Note: the<br />
isolation sub is used to<br />
prevent pressure from going<br />
upward from the Select Fire Sub).<br />
Air<br />
Chamber<br />
TDF Firing<br />
Head<br />
®<br />
VannGun<br />
Assembly<br />
Select Fire Tubing Conveyed<br />
<strong>Perforating</strong> System<br />
®<br />
VannGun<br />
Assembly<br />
Pressure<br />
Isolation<br />
Sub<br />
Sealed Initiator<br />
Select Fire<br />
Sub<br />
Air Chamber<br />
<strong>Perforating</strong> Solutions 5-141<br />
HAL10586
Coiled Tubing Conveyed <strong>Perforating</strong><br />
Conveying perforating guns to the zone<br />
of interest with coiled tubing has been<br />
effectively used for many years in a<br />
variety of applications. Benefits include<br />
faster run-in times when compared to<br />
conventional methods. And the guns<br />
can be detonated either with wireline or<br />
a pressure-activated firing head. Some<br />
of the applications include:<br />
<strong>Perforating</strong> in Underbalanced<br />
Conditions<br />
Underbalanced conditions occur<br />
when hydrostatic pressure in the well<br />
is lower than formation pressure.<br />
Perforation under these conditions<br />
allows increased flow from the<br />
formation, which helps clean the<br />
perforations <strong>and</strong> helps reduce nearwellbore<br />
damage<br />
Horizontal Well <strong>Perforating</strong><br />
Coiled tubing conveyed perforating<br />
could be deployed in horizontal<br />
portions of the well where<br />
conventional methods of perforating<br />
are impractical or impossible<br />
Coiled Tubing Used as the<br />
Production String<br />
The coiled tubing that conveys the<br />
perforating guns can also be used as<br />
the production tubing after well<br />
completion<br />
Special features include an automaticrelease<br />
gun hanger, which allows the<br />
coiled tubing to detach from the<br />
perforating guns before they are fired,<br />
avoiding damage to the coiled tubing. A<br />
modular gun system is also available in<br />
which the perforating guns are loaded<br />
at the surface, deployed downhole<br />
individually, <strong>and</strong> stacked at the<br />
perforating zone. This method helps<br />
eliminate any gun length restrictions<br />
caused by the lubricator.<br />
HAL15399<br />
Correlation Tool Stack<br />
Coiled Tubing<br />
Connector<br />
Swivel<br />
Back Pressure<br />
Valve<br />
Hydraulic<br />
Disconnect<br />
Circulating<br />
Valve<br />
Crossover<br />
Centralizer<br />
Battery<br />
Housing<br />
Memory<br />
Controller<br />
Pressure<br />
Casing Collar<br />
Locator (CCL)<br />
Gamma/Ray<br />
Temperature<br />
Roller<br />
Centralizer<br />
<strong>Perforating</strong> Gun String<br />
Coiled Tubing<br />
Connector<br />
Swivel<br />
Back Pressure<br />
Valve<br />
Hydraulic<br />
Disconnect<br />
Pressure Relief<br />
Ports*<br />
Coiled Tubing<br />
<strong>and</strong> Firing Head<br />
Crossover<br />
Firing Head<br />
with Circulating<br />
Ports<br />
3 3/8-in.-6TTP<br />
Scalloped Guns<br />
*Pressure relief ports are added to the BHA for<br />
coiled tubing perforating jobs to help eliminate<br />
the possibility of a pressure increase due to<br />
thermal expansion in a closed chamber.<br />
5-142 <strong>Perforating</strong> Solutions<br />
HAL15400
DrillGun <strong>Perforating</strong> Systems<br />
<strong>Halliburton</strong> has developed the<br />
DrillGun assembly to be a drillable<br />
perforating system that provides<br />
reliable, quality performance while<br />
lowering overall wellsite costs by:<br />
Eliminating the high costs associated<br />
with wireline services<br />
Eliminating the need to switch to a<br />
mud system for workovers<br />
The DrillGun perforating system is a<br />
new method that combines rugged,<br />
reliable <strong>Halliburton</strong> perforating<br />
components with the versatility of<br />
drillable materials. It is this type of<br />
innovative design that has made<br />
<strong>Halliburton</strong> the leader in perforating<br />
charge performance <strong>and</strong> delivery<br />
systems. Now, with the DrillGun<br />
perforating system, you have a drillable,<br />
disposable system that helps save you<br />
two of the most valuable commodities<br />
at the wellsite—time <strong>and</strong> money.<br />
Components of the drillable<br />
perforating system are the drillpipe<br />
conveyed to the zone of interest;<br />
thereby eliminating mobilization or<br />
demobilization charges normally<br />
associated with wireline units. And,<br />
since no mud system is needed, clear<br />
fluids can remain in place for workover<br />
operations. Once in place, the firing<br />
head is actuated by pressure applied<br />
through the tubing. After perforating,<br />
the gun can be drilled out with<br />
conventional drilling methods.<br />
The drillable perforating system is ideal<br />
for:<br />
Single-trip perforating, packer<br />
placement, <strong>and</strong> cementing on tubing<br />
Cementing <strong>and</strong> perforating in<br />
underbalanced conditions<br />
Plug-to-ab<strong>and</strong>on operations<br />
Workover cementing with clear fluids<br />
Plugback set on wireline<br />
Limited entry drill stem testing<br />
Components of the drillable<br />
perforating system include:<br />
Aluminum perforating gun<br />
High-performance, perforating<br />
charges<br />
<strong>Halliburton</strong>’s industry-proven<br />
EZ Drill® SVB packer<br />
DrillGun Assembly<br />
<strong>Perforating</strong> Solutions 5-143<br />
HAL12056
DrillGun <strong>Perforating</strong> System - Quick, Economical Solution For<br />
<strong>Perforating</strong> In Unusual Conditions.<br />
Savings on Rig Time<br />
Operator's challenge—Carrizo Oil &<br />
Gas, Inc. needed to perform a squeeze<br />
job on a South Texas well. The<br />
customer had already switched to a<br />
lighter drilling fluid <strong>and</strong> did not want<br />
the high cost of changing to a mud<br />
system. As a result, the well would have<br />
to be perforated underbalanced.<br />
<strong>Halliburton</strong>'s solution—To meet this<br />
challenge, <strong>Halliburton</strong> recommended<br />
its DrillGun system.<br />
Economic value created—As a result,<br />
Carrizo was able to perform the squeeze<br />
job without having to replace the<br />
lighter drilling fluid with an expensive<br />
mud system. This procedure saved rig<br />
time <strong>and</strong> the expense of a fluid change<br />
for a total economic value to the<br />
customer of $20,000.<br />
SAP No.<br />
101288693<br />
Aluminum<br />
101288692<br />
Aluminum<br />
101292015<br />
Composite<br />
Thread Size<br />
<strong>and</strong> Type<br />
in. (mm)<br />
2 7/8 (73.03)<br />
EUE 8 Rd<br />
2 7/8 (73.03)<br />
EUE 8 Rd<br />
2 7/8 (73.03)<br />
EUE 8 Rd<br />
Block Squeeze Application<br />
Operator's challenge—An operator<br />
working in the Permian Basin had to<br />
perform three block squeezes in a<br />
7 5/8 in. liner from 14,400 ft to<br />
14,800 ft. A primary cement job had<br />
not been possible, so instead of cement<br />
behind the casing, there was 15.5 ppg<br />
drilling mud. The well fluid was 10 ppg<br />
brine water. However, it would not be<br />
necessary to change the well fluid to<br />
15.5 ppg drilling mud to cement.<br />
<strong>Halliburton</strong>'s solution— <strong>Halliburton</strong><br />
logged the first DrillGun system on<br />
depth, perforated <strong>and</strong> performed the<br />
cement job at 4,230 psi underbalanced.<br />
For the next two DrillGun system runs,<br />
we tagged the first retainer <strong>and</strong> located<br />
it on depth to perform the squeeze.<br />
Economic value created—The three<br />
aluminum perforating guns added only<br />
one hour each to the drill-out time. The<br />
customer estimates that this procedure<br />
saved $52,000.<br />
DrillGun Assembly Specifications<br />
Maximum OD<br />
in. (mm)<br />
4.00<br />
(101.6)<br />
7.00<br />
(177.8)<br />
3.625<br />
(92.1)<br />
*For use in wells above 300°F (148.89°C), consult a <strong>Halliburton</strong> representative.<br />
Maximum Operating<br />
Pressure<br />
psi (bar)<br />
15,000<br />
(1020)<br />
12,000<br />
(816)<br />
15,000<br />
(1020)<br />
Plug-to-Ab<strong>and</strong>on<br />
Operator's challenge—To plug a well<br />
before ab<strong>and</strong>oning it, an operator in<br />
Chambers County, Texas needed to<br />
perforate six zones.<br />
<strong>Halliburton</strong>'s solution—<strong>Halliburton</strong><br />
recommended using its DrillGun rather<br />
than employing electric-line<br />
perforators which would normally be<br />
selected for the project. The first<br />
DrillGun system was started in the well<br />
on Sunday evening <strong>and</strong> was set the next<br />
day at a depth of 13,050 ft. The bottom<br />
zone was then squeezed. After the<br />
procedure was completed, the setting<br />
assembly was pulled out of the hole. It<br />
went back in with the second stage, <strong>and</strong><br />
the job was performed at 8,590 ft. The<br />
next day, the final four jobs were run at<br />
5,500 ft, 2,615 ft, 500 ft, <strong>and</strong> 350 ft,<br />
respectively.<br />
Economic value created—All six stages<br />
were completed in 2 1/2 days. If<br />
electric-line perforators had been used,<br />
the total job would have taken up to six<br />
days. By using the <strong>Halliburton</strong><br />
DrillGun system, the operator saved<br />
four days of rig-associated costs,<br />
consultants, <strong>and</strong> fluid st<strong>and</strong>by time. An<br />
additional savings was realized by using<br />
the perforating DrillGun system instead<br />
of more expensive electric-line charges.<br />
The resulting estimated economic value<br />
to the customer is $24,200.<br />
Minimum Operating<br />
Pressure<br />
psi (bar)<br />
3,500<br />
(241)<br />
3,500<br />
(241)<br />
3,500<br />
(241)<br />
Temperature<br />
Rating<br />
°F (°C)<br />
300<br />
(148.9)*<br />
300<br />
(148.9)*<br />
300<br />
(148.9)*<br />
Maximum<br />
Overall Length<br />
ft (m)<br />
4.40<br />
(1.341)<br />
4.40<br />
(1.341)<br />
3.95<br />
(1.204)<br />
5-144 <strong>Perforating</strong> Solutions
Setting Tools for the Auto-Release Gun Hanger<br />
Running <strong>and</strong> Retrieving Tools<br />
The running <strong>and</strong> retrieving tools for the modular gun system<br />
<strong>and</strong> the auto-release gun hanger gives customers flexibility in<br />
the conveyance of these tools in the well. There are four basic<br />
running tools that have been run with these systems:<br />
explosive set, jar down, hydraulic, <strong>and</strong> rotational set. Most of<br />
the tools are for wireline <strong>and</strong> slickline deployment of the<br />
systems. The on/off tool requires rotation to operate <strong>and</strong> is<br />
limited to tubing conveyed applications. All of these tools are<br />
reusable with a minimal amount of redressing.<br />
Application<br />
The running <strong>and</strong> retrieving tools are used for setting gun<br />
hangers in position, running modules, <strong>and</strong> retrieving<br />
modules. The tools break down into four categories:<br />
explosive set, jar down <strong>and</strong> jar up, hydraulic, <strong>and</strong> rotational<br />
set. There are many tools that can be used with the modular<br />
system. This manual has been written for the tools specially<br />
designed for the modular gun system or those recognized as a<br />
usable tool.<br />
Explosive set<br />
–Adapter kit for Baker #10 setting tool<br />
–Adapter kit for Baker #20 setting tool<br />
Jar down<br />
–Otis® SB <strong>and</strong> RB shear release <strong>and</strong> running tool<br />
–Camco JDC <strong>and</strong> JUC<br />
Hydraulic<br />
–Hydraulic JDC running <strong>and</strong> retrieving tool<br />
Rotational set<br />
–Right h<strong>and</strong> release on/off tool<br />
Running Tool Assembly Modular<br />
3.12 in. OD for Baker #20 Setting Tool<br />
<strong>Perforating</strong> Solutions 5-145<br />
HAL15778
5-146 <strong>Perforating</strong> Solutions
Downhole Video<br />
Downhole Video <strong>Services</strong><br />
Equipment providing real-time videos of actual oil<br />
production into wellbores through perforations, <strong>and</strong> the<br />
resulting flow up production tubulars, enhance the ability to<br />
characterize fluid inflow on a perforation-specific basis.<br />
The visually intuitive nature of downhole video data results<br />
in greatly increased effectiveness of conformance technology<br />
treatments, leading to increased oil <strong>and</strong> gas production <strong>and</strong><br />
decreased water production. Greater knowledge of the type<br />
of fluid being produced from each perforation substantially<br />
reduces the risk of inadvertently shutting off oil or gas<br />
production with misplaced treatments.<br />
Features<br />
A downhole video survey allows observation of the integrity<br />
of the casing or tubing to find holes, cracks, or corroded<br />
areas <strong>and</strong> fluid entry or exit points. Also, it can detect scale or<br />
bacteria buildup, which can impede the flow of<br />
hydrocarbons out of the wellbore <strong>and</strong> reduce the ID of the<br />
wellbore tubulars <strong>and</strong> plug slotted liners, gravel pack screens,<br />
or perforations.<br />
Downhole video can help the operator detect <strong>and</strong> identify<br />
phase entry, fluid flow, <strong>and</strong> s<strong>and</strong> or particulate matter entry<br />
into the wellbore.<br />
The video survey can detect the entry of s<strong>and</strong> <strong>and</strong> particulate<br />
matter from individual perforations. Conventional flowmeasurement<br />
tools often cannot detect such subtle changes<br />
in fluid activity. Oil bubbling into the wellbore does not<br />
disrupt the surrounding well fluids. The oil remains in<br />
bubbles <strong>and</strong> migrates to the high side of the well, causing<br />
Max Deployment Depth<br />
ft (m)<br />
14,000<br />
(4267)<br />
Camera Assembly OD<br />
in. (mm)<br />
1.687<br />
(42.8)<br />
Downhole Video <strong>Services</strong> Specifications<br />
Maximum Pressure<br />
psi (Mpa)<br />
10,000<br />
(69)<br />
some of the oil to bypass conventional logging tools. Video<br />
surveying clearly identifies the oil-producing perforations.<br />
A downhole video survey documents the amount of gas <strong>and</strong><br />
oil being produced at each point in a producing interval.<br />
Conventional flowmeters directly measure the average flow<br />
rate of a column of fluid. The downhole video survey does<br />
not directly measure absolute flow rates but is used to<br />
quantify relative flow rates along the production intervals.<br />
Downhole video surveys can visually confirm the initial<br />
analysis of conformance problems <strong>and</strong> determine if the<br />
prescribed treatment can solve the problem. If the initial<br />
analysis was incorrect, the visual information can be used to<br />
modify the treatment schedule to prevent costly but<br />
ineffective treatment procedures.<br />
Downhole video can monitor well <strong>and</strong> reservoir treatments<br />
in real-time during the treatment process. For example,<br />
downhole video surveys run during a frac job can verify<br />
that the frac proppant entered the intended fracture areas.<br />
The downhole video is limited by fluid clarity, the<br />
operational limits of the camera <strong>and</strong> system, <strong>and</strong> extremely<br />
high flow rates.<br />
After the completion of a treatment, a downhole video<br />
survey can show whether the treatment successfully treated<br />
the problem area. Video confirmation of the job results also<br />
allows operators to learn more about the effectiveness of the<br />
treatment to continually improve the treatment process.<br />
Maximum Temperature<br />
°F (°C)<br />
Cable Tension Limits<br />
lb (kg)<br />
at Camera Cable Head at Surface<br />
Downhole Video 6-1<br />
225<br />
(107)<br />
500<br />
(226.8)<br />
1,200<br />
(544.3)<br />
Downhole Video
Hawkeye Camera System<br />
The Hawkeye camera system allows operators to view<br />
conditions inside oil <strong>and</strong> gas wells without the need for a<br />
special coaxial or fiber-optic cable. Video images (frames) are<br />
transmitted to the surface every 1.7 seconds over st<strong>and</strong>ard<br />
electric line logging cable. Complete redundancy for all<br />
mission critical components is provided along with rugged<br />
shipping containers for complete transportability. The<br />
camera requires a transparent medium in the area to be<br />
filmed for meaningful results. Obtaining the correct clarity of<br />
fluid at the viewing zone is often the most challenging aspect<br />
of performing this service.<br />
The camera is used as a diagnostic tool to detect all types of<br />
fluid <strong>and</strong> solids entry into the borehole, to inspect pipe for<br />
corrosion, mechanical integrity, <strong>and</strong> correct production/<br />
perforation verification. Additionally it may be used to aid<br />
fishing operations.<br />
Features<br />
The Hawkeye system can be run from any logging cable<br />
with less than 250 ohms total loop resistance <strong>and</strong> up to<br />
1.5 micro farads of total capacitance. This allows<br />
downhole video service to be offered as the system is<br />
completely transportable to any location without the<br />
need for special cable or logging units<br />
The ability to measure depth <strong>and</strong> superimpose it on the<br />
video image along with time, date, <strong>and</strong> internal tool<br />
temperature is provided. In addition, the ability to<br />
Length<br />
ft (m)<br />
8.5<br />
(2.6)<br />
Hawkeye Camera System Specifications<br />
Diameter<br />
in. (mm)<br />
1.69<br />
(42.9)<br />
annotate the recorded tape with text entered from an<br />
optional laptop computer or video typewriter is<br />
provided<br />
The system comes equipped with two downhole tools,<br />
two surface power supply/receivers, <strong>and</strong> two video<br />
monitors. This provides complete backup for the image<br />
producing <strong>and</strong> display equipment<br />
The system is provided in three rugged shipping<br />
containers with internal padding designed for the<br />
st<strong>and</strong>ard components plus some additional room for<br />
cables <strong>and</strong> miscellaneous equipment<br />
This image shows cut up casing that has fallen onto a trash cap for a<br />
casing shoe.<br />
6-2 Downhole Video<br />
HAL11281<br />
Maximum Pressure<br />
psi (Mpa)<br />
10,000<br />
(69.0)<br />
Maximum Temperature<br />
°F (°C)<br />
250<br />
(121.1)<br />
Weight<br />
lb (kg)<br />
31<br />
(14.1)
Fiber-Optic Camera System<br />
The fiber-optic system allows operators to view conditions<br />
inside oil <strong>and</strong> gas wells. Video images (frames) are<br />
transmitted to the surface at a rate of 30 frames every second<br />
over a specialty 0.25-in. diameter logging cable with a fiberoptic<br />
cable at its center. Complete redundancy for all mission<br />
critical components is provided along with rugged shipping<br />
containers for complete transportability. The camera<br />
requires a transparent medium in the area to be filmed for<br />
meaningful results. Obtaining the correct clarity of fluid at<br />
the viewing zone is often the most challenging aspect of<br />
performing this service.<br />
The camera is used as a diagnostic tool to detect all types of<br />
fluid <strong>and</strong> solids entry into the borehole, <strong>and</strong> to inspect pipe<br />
for corrosion, mechanical integrity, <strong>and</strong> correct production/<br />
perforation verification. Additionally, it may be used to aid<br />
fishing operations.<br />
The fiber-optic system differentiates itself from other video<br />
camera tools by having the highest video data rate <strong>and</strong> is<br />
better than any other products available for detecting flow<br />
due to gas entry.<br />
Length<br />
ft (m)<br />
9.5<br />
(2.9)<br />
Fiber-Optic Camera System Specifications<br />
Diameter<br />
in. (mm)<br />
1.69<br />
(42.9)<br />
Maximum Pressure<br />
psi (Mpa)<br />
10,000<br />
(69.0)<br />
Features<br />
A 1.6875-in. backlight camera is used to provide<br />
unobstructed, wide viewing angle, <strong>and</strong> clearly defined<br />
images. A 10,000 psi pressure rating <strong>and</strong> operation at<br />
temperatures up to 250°F are st<strong>and</strong>ard<br />
The ability to measure depth <strong>and</strong> superimpose it on the<br />
video image along with time, date, <strong>and</strong> internal tool<br />
temperature is provided. In addition, the system has the<br />
ability to annotate the recorded tape with text entered<br />
from an optional laptop computer or video typewriter<br />
The system comes equipped with two downhole tools,<br />
two surface power supply/receivers, <strong>and</strong> two video<br />
monitors. This provides complete backup for the image<br />
producing <strong>and</strong> display equipment<br />
The system is provided in three rugged shipping<br />
containers with internal padding designed for the<br />
st<strong>and</strong>ard components plus some additional room for<br />
cables <strong>and</strong> miscellaneous equipment<br />
The fiber optic system’s resolution is 550 × 350 lines vs.<br />
the 317 × 262 lines of the Hawkeye system. As a result,<br />
the fiber-optic system has better picture resolution <strong>and</strong><br />
provides pictures virtually in real time. By comparison,<br />
the Hawkeye system is more akin to a slo-scan security<br />
camera<br />
Maximum Temperature<br />
°F (°C)<br />
250<br />
(121.1)<br />
Weight<br />
lb (kg)<br />
Downhole Video 6-3<br />
35<br />
(15.9)
EyeDeal Camera System<br />
Pictures are said to be worth a thous<strong>and</strong> words—<strong>and</strong> they<br />
become even more powerful when they are transmitted from<br />
wellbores miles beneath the Earth’s surface. <strong>Halliburton</strong>’s<br />
EyeDeal camera system opens new windows to the<br />
downhole world with high-resolution images that eliminate<br />
the guesswork from a range of diagnostic tests <strong>and</strong><br />
troubleshooting operations.<br />
HAL18524<br />
HAL18523<br />
Downhole<br />
Camera View<br />
HAL18525<br />
Sideview camera with<br />
view angle that is closer<br />
<strong>and</strong> almost dead-on to<br />
the camera lens<br />
The EyeDeal camera system can be deployed in two ways:<br />
Fiber-optic configuration – When attached to the fiberoptic<br />
system, the EyeDeal camera system can operate to a<br />
depth of 14,000 ft <strong>and</strong> can sustain pressures of 10,000 psi<br />
<strong>and</strong> temperatures of 250°F. In this configuration, the<br />
EyeDeal camera system offers a continuous-feed image<br />
with an excellent screen resolution of 550 × 350<br />
Hawkeye system configuration – When attached to the<br />
Hawkeye system, the EyeDeal camera system uses<br />
existing logging cables to transmit high-quality images<br />
(screen resolution: 317 × 262) at the rate of one frame<br />
every 1.7 seconds. The Hawkeye system provides full<br />
remote camera operation <strong>and</strong> control, <strong>and</strong> its advantages<br />
include deeper operation <strong>and</strong> the ability to perform<br />
flawlessly in corrosive fluids<br />
Fiber Optic Configuration:<br />
Down View, Real Time<br />
Hawkeye Configuration:<br />
Snapshots, Every 1.7 Seconds<br />
Fiber Optic Configuration:<br />
Side View, Real Time<br />
Applications of the EyeDeal camera system include quality<br />
assurance inspection, gas entry, water entry, fishing<br />
operations, casing <strong>and</strong> perforation inspection, <strong>and</strong> general<br />
problem identification.<br />
The technology incorporated in the fiber-optic <strong>and</strong> Hawkeye<br />
systems allows operators to toggle between downview <strong>and</strong><br />
sideview images. The sideview lens records images<br />
perpendicular to the borehole wall <strong>and</strong> gives a true 360° view.<br />
This is especially useful in large-diameter wellbores (from 16<br />
to 30 in.) where traditional downview cameras offer only a<br />
limited field of vision. The EyeDeal camera system can be<br />
toggled between downview <strong>and</strong> sideview images, giving<br />
operators the valuable advantage of being able to isolate <strong>and</strong><br />
study an area of interest.<br />
6-4 Downhole Video<br />
HAL18526<br />
HAL18528<br />
HAL18527
EyeDeal Camera System Examples<br />
HAL18526<br />
HAL18529<br />
HAL18532<br />
Suspect Latch Found OK, DV Latch Issues Due to Debris, SV Damaged Flow Tube, DV<br />
Fishing Operation 1 of 3 Fishing Operation 2 of 3 Fishing Operation 3 of 3<br />
5.5-in. Lubricator<br />
HAL18527<br />
HAL18530<br />
HAL18533<br />
Perfs Before Cleanout, DV<br />
Perfs After Cleanout, DV<br />
EyeDeal Camera System Specifications: Sideview <strong>and</strong> Downview Combination<br />
Length<br />
ft (in.)<br />
9.75<br />
(117)<br />
Length<br />
ft (mm)<br />
8.5<br />
(2.6)<br />
Diameter<br />
in. (mm)<br />
1.937<br />
(49.2)<br />
Diameter<br />
in. (mm)<br />
1.687<br />
(42.9)<br />
Maximum Pressure<br />
psi (Mpa)<br />
10,000<br />
(69)<br />
Downhole Video 6-5<br />
HAL18528<br />
HAL18531<br />
HAL18534<br />
Maximum Temperature<br />
°F (°C)<br />
250<br />
(121.1)<br />
Downview Camera Specifications<br />
Maximum Pressure<br />
psi (Mpa)<br />
10,000<br />
(69)<br />
Maximum Temperature<br />
°F (°C)<br />
250<br />
(121.1)<br />
Weight<br />
lb (kg)<br />
36<br />
(16.3)<br />
Weight<br />
lb (kg)<br />
31<br />
(14.1)
6-6 Downhole Video
Slickline Service Equipment <strong>and</strong> <strong>Services</strong><br />
The high quality of <strong>Halliburton</strong>’s slickline services depends<br />
upon the capabilities of its service tools <strong>and</strong> equipment;<br />
therefore, we are committed to designing <strong>and</strong> manufacturing<br />
the most sophisticated tools in the industry. Our success in<br />
this endeavor, along with highly trained <strong>and</strong> experienced<br />
personnel, has allowed us to remain the leader of the slickline<br />
service industry.<br />
Through our decades of experience <strong>and</strong> global presence,<br />
<strong>Halliburton</strong> has continued to offer the industry the most<br />
complete line of slickline service equipment, tools, <strong>and</strong><br />
services.<br />
Slickline Service Equipment 7-1<br />
Slickline Service Equipment
Subsurface Service Tools<br />
Slickline Service Tools<br />
Otis® designed <strong>and</strong> manufactured slickline service tools have<br />
been the benchmark for the industry <strong>and</strong> are a requirement<br />
for all toolboxes worldwide. Known for dependable<br />
performance <strong>and</strong> low maintenance costs, these service tools<br />
can help reduce your total operating costs. As the original<br />
equipment manufacturer (OEM), <strong>Halliburton</strong> continues to<br />
provide high-quality slickline service tools.<br />
Slickline Toolstring<br />
<strong>Wireline</strong> Toolstring<br />
A wireline toolstring is attached to the wireline to furnish the<br />
mechanical force necessary for setting, pulling, or servicing<br />
subsurface equipment under pressure without killing the<br />
well. Toolstrings are available in various ODs <strong>and</strong><br />
component lengths designed to be compatible with various<br />
tubing sizes.<br />
Otis Rope Sockets<br />
Otis rope sockets provide a means for connecting the<br />
wireline to the toolstring. The wireline is tied around a disc<br />
or dart in the socket to achieve a firm connection.<br />
Otis Stems<br />
Otis stems are used as weight to overcome stuffing-box<br />
packing friction <strong>and</strong> well pressure on the cross-sectional area<br />
of the wireline. The stem can also transmit force either<br />
upward or downward to set or retrieve subsurface controls.<br />
Size <strong>and</strong> weight of the stem are determined by the impact<br />
force required <strong>and</strong> the size of the subsurface control to be run<br />
or pulled. For normal conditions, 5 ft of 1 1/2-in. OD stem is<br />
made up by combining 2-, 3-, or 5-ft (0.61, 0.91, 1.22 m)<br />
lengths of st<strong>and</strong>ard stem. For high-pressure applications<br />
when additional weight is needed, lead or mallory-filled<br />
stems are available.<br />
7-2 Slickline Service Equipment<br />
HAL8500<br />
<strong>Wireline</strong> Socket<br />
Stem<br />
Jars<br />
Typical String of<br />
<strong>Wireline</strong> Tools<br />
Knuckle Joint<br />
Running or<br />
Pulling Tool<br />
HAL8501<br />
Otis® Rope Socket<br />
HAL8502<br />
Otis® Stem
Otis ® Accelerators<br />
Otis® accelerators are used with <strong>and</strong> just above hydraulic jars<br />
for shallow, weighty jarring. Accelerators help maintain<br />
constant pull as the hydraulic jars begin to open. The<br />
accelerator inhibits pulling the wireline out of the wireline<br />
socket at these shallow depths.<br />
Otis Knuckle Joints<br />
Otis knuckle joints have a special ball <strong>and</strong> socket design,<br />
allowing angular movement between the jars <strong>and</strong> the<br />
running or pulling tool to help align them with the tubing.<br />
Knuckle joints are important if the tubing is corkscrewed <strong>and</strong><br />
when wireline work is done in a directional hole. In these<br />
conditions, joints are used at every connection in the<br />
toolstring. Where stem <strong>and</strong> jars will not align or move freely,<br />
tool operation may be impossible; however, the knuckle joint<br />
inhibits the wireline tools from hanging up.<br />
Otis Jars<br />
Otis jars are available in mechanical <strong>and</strong> hydraulic types.<br />
With a set of mechanical jars below the stem, the weight of<br />
the jars <strong>and</strong> stem can be used to jar up or down by pulling<br />
<strong>and</strong> releasing the wireline. A <strong>Halliburton</strong> wireline specialist<br />
can easily feel the jars <strong>and</strong> manipulate the wireline. Hydraulic<br />
jars are designed to provide jarring action in wells in which it<br />
is difficult to obtain good jarring action with mechanical jars.<br />
Hydraulic jars, which allow an upward impact only, are<br />
usually run just above the regular mechanical jars. They<br />
require careful maintenance for maximum use in the<br />
toolstring. Jar operation is monitored by a weight indicator.<br />
Otis B Blind Box<br />
Otis B blind box serves as the impact point when downward<br />
jarring operations are required.<br />
St<strong>and</strong>ard <strong>Wireline</strong> Toolstring<br />
Normal Tool OD<br />
in. (mm) Thread Connection*<br />
3/4<br />
(19.05)<br />
5/8 in. - 11 UNC<br />
1<br />
(25.40)<br />
5/8 in. - 11 UNC<br />
1 1/4<br />
(31.75)<br />
15/16 in. - 10 UNS<br />
1 1/2<br />
(38.10)<br />
15/16 in. - 10 UNS<br />
1 7/8<br />
(47.63)<br />
1 1/16 in. - 10 UNS<br />
2<br />
(50.80)<br />
1 1/16 in. - 10 UNS<br />
2 1/2<br />
(63.50)<br />
1 1/16 in. - 10 UNS<br />
*Other thread connections available<br />
Fishneck OD<br />
in. (mm)<br />
0.750<br />
(19.05)<br />
1.000<br />
(25.40)<br />
1.188<br />
(30.18)<br />
1.375<br />
(34.93)<br />
1.750<br />
(44.45)<br />
1.750<br />
(44.45)<br />
2.313<br />
(58.75)<br />
Slickline Service Equipment 7-3<br />
HAL8503<br />
Otis® Knuckle Joint<br />
HAL8505<br />
Otis®<br />
Mechanical Jar<br />
HAL8504<br />
HAL8506 Otis® Blind Box<br />
Otis®<br />
Hydraulic Jar<br />
HAL8507<br />
Otis®<br />
Accelerator
Slickline Detent Jars<br />
The <strong>Halliburton</strong> detent jar is a mechanically operated jar that<br />
is run on slickline or wireline to deliver an impact through<br />
the toolstring when the release setting is overcome by<br />
tension. This jar has adjustable stroke <strong>and</strong> release settings<br />
that are predetermined on the surface prior to running the<br />
jar. The detent jar can be run with accelerator, weight bar,<br />
<strong>and</strong> link-type or Spang jars for delivering an optimum<br />
impact load for releasing a stuck object or operating a<br />
downhole tool. The detent jar is re-settable downhole by<br />
slacking weight at the jar to a collapsed mode. The jar can be<br />
tripped <strong>and</strong> reset rapidly <strong>and</strong> multiple times downhole.<br />
There are no seals in the detent jar, so bottomhole<br />
temperature or pressure has minimal effect on the jar<br />
operation.<br />
Sometimes in deep <strong>and</strong> deviated wells, the line tension on the<br />
weight indicator at the surface is not the same line tension at<br />
the rope socket. Modeling the slickline job with Cerberus<br />
will provide calculated rope socket line tensions.<br />
Size<br />
in. (mm)<br />
1.500<br />
(38.10)<br />
1.875<br />
(47.63)<br />
2.250<br />
(57.15)<br />
St<strong>and</strong>ard Release<br />
lb (kg)<br />
up to 900<br />
(up to 408)<br />
up to 1,400<br />
(up to 635)<br />
up to 3,100<br />
(up to 1406)<br />
High Release<br />
lb (kg)<br />
750 to 2,100<br />
(340 to 953)<br />
1,300 to 3,500<br />
(590 to 1588)<br />
1,250 to 5,000<br />
(567 to 2268)<br />
Detent Jars<br />
Stroke<br />
in. (mm)<br />
8 to 14<br />
(203.2 to 355.6)<br />
8 to 14<br />
(203.2 to 355.6)<br />
8 to 14<br />
(203.2 to 355.6)<br />
Length<br />
in. (mm)<br />
52<br />
(1320.8)<br />
53<br />
(1346.2)<br />
50<br />
(1270)<br />
Tensile<br />
lb (kg)<br />
37,500<br />
(17 010)<br />
62,000<br />
(28 123)<br />
76,000 lb<br />
(34 473)<br />
Slickline Detent Jar<br />
7-4 Slickline Service Equipment
Otis ® Quick Connect Toolstring Connection<br />
Before its extensive field history, the Otis® quick connect was<br />
thoroughly tested in both the engineering laboratory <strong>and</strong> the<br />
<strong>Halliburton</strong> test well in Carrollton, Texas. During the design<br />
proving phase, a 1 1/2-in. (38.1 cm) Otis quick connect was<br />
jarred through 50,000 cycles at impact loads of 9,000 to<br />
10,000 lb (4082.33 to 4535.92 kg) in both directions. Tensile<br />
testing on the tool after jarring revealed the Otis quick<br />
connect had retained full strength throughout the operation.<br />
Now <strong>Halliburton</strong> toolstring components <strong>and</strong> wireline service<br />
tools are available with integral Otis quick connects.<br />
Features<br />
Spacing of load-bearing shoulders will not allow<br />
coupling to connect until full engagement of all<br />
shoulders are in place<br />
Self-washing feature minimizes s<strong>and</strong> buildup in the<br />
locking mechanism<br />
Designed for manual operation; no special tools required<br />
Otis quick connect design ensures proper toolstring<br />
makeup<br />
Reliable disconnect, even in s<strong>and</strong>y environment<br />
Safe assembly/disassembly on location<br />
Faster turnaround on location minimizes job time<br />
Slickline Service Equipment 7-5<br />
HAL11442<br />
Mechanical<br />
<strong>Wireline</strong> Jar<br />
HAL11443<br />
<strong>Wireline</strong> Quick<br />
Connect Stem<br />
HAL11444<br />
Knuckle Joint<br />
Quick Connect
Auxiliary Tools For Use with Slickline Toolstring<br />
Otis ® Gauge Cutter <strong>and</strong> Swaging Tools<br />
It is important to run a gauge cutter before running<br />
subsurface controls to: (1) determine if the flow control will<br />
pass freely through the tubing <strong>and</strong> (2) to locate the top of the<br />
l<strong>and</strong>ing nipple or restriction if any are in the tubing. The<br />
gauge cutter knife (larger than OD of the control) is designed<br />
to cut away paraffin, scale, <strong>and</strong> other debris in the tubing.<br />
Mashed spots in the tubing <strong>and</strong> large obstructions may be<br />
removed with the swaging tool. These tools are available in<br />
sizes for all tubing IDs.<br />
Otis Impression Tool<br />
Otis® impression tool is a lead-filled cylinder with a pin<br />
through the leaded section to secure it to the body of the tool.<br />
It is used during a fishing operation to ascertain the shape or<br />
size of the top of the fish <strong>and</strong> to indicate the type of tool<br />
necessary for the next operation.<br />
Otis Tubing Broach<br />
Otis tubing broach is made up of three major parts: (1)<br />
m<strong>and</strong>rel, (2) nut, <strong>and</strong> (3) a set of three spools. Spools are<br />
tapered <strong>and</strong> used to cut burrs in the tubing ID caused by<br />
perforation, rust, bent tubing, etc. A small OD spool is run<br />
first followed by the next larger size, followed by a spool<br />
corresponding to the original ID of the tubing. Broach<br />
assemblies are run on wireline.<br />
Otis M Magnetic Fishing Tool<br />
Otis M magnetic fishing tool is designed to remove small<br />
particles of ferrous metals from the top of tools in the well.<br />
7-6 Slickline Service Equipment<br />
HAL8510<br />
HAL8508<br />
Otis® Swaging Tool Otis® Gauge Cutter<br />
Otis® Impression<br />
Tool<br />
HAL8511<br />
Otis® Tubing Broach<br />
HAL8509<br />
HAL8512<br />
Otis® M Magnetic<br />
Fishing Tool
Otis ® G Fishing Socket<br />
Otis® G fishing socket was designed primarily to extract<br />
prongs with fishing necks from <strong>Halliburton</strong> subsurface<br />
equipment, such as the Otis PS plug choke.<br />
Otis P <strong>Wireline</strong> Grab<br />
Otis P wireline grab is a fishing tool designed to extract<br />
broken wireline or cable from the tubing or casing.<br />
Otis Go-Devil<br />
Otis go-devil is a slotted stem with a fishing neck. Should the<br />
tool become stuck, the go-devil can be attached to the<br />
slickline via a small strip of metal pinned in the slot to keep<br />
the wireline from coming out. The go-devil is dropped from<br />
surface <strong>and</strong> will slide down the wire until it hits a restriction<br />
or the top of the rope socket. The go-devil will cut the<br />
slickline at that point, allowing the slickline to be retrieved.<br />
Its use is usually limited to fishing operations where the<br />
wireline socket is inaccessible <strong>and</strong> the line must be cut. Otis<br />
go-devils designed to cut the wireline at the wireline socket<br />
are also available.<br />
Exp<strong>and</strong>able Wirefinder<br />
The exp<strong>and</strong>able wirefinder is designed to locate wireline lost<br />
below a tubing restriction (such as a TRSV). The exp<strong>and</strong>able<br />
wirefinder is held retracted in a sleeve which is run, located,<br />
<strong>and</strong> preferably latched in the restriction in the tubing. The<br />
wirefinder is then sheared out of the sleeve allowing it to<br />
exp<strong>and</strong> to the ID of the tubing. Once the lost wireline is<br />
found <strong>and</strong> deformed, the wirefinder can be returned to its<br />
running sleeve <strong>and</strong> retracted for retrieval. A wireline grab is<br />
then run to latch <strong>and</strong> retrieve the lost wireline.<br />
Slickline Service Equipment 7-7<br />
HAL8515<br />
HAL8513<br />
Otis® G Fishing Socket<br />
Otis® Go-Devil<br />
HAL14025<br />
Run-in<br />
Position<br />
HAL8514<br />
Otis® P <strong>Wireline</strong> Grab<br />
Otis® Exp<strong>and</strong>able Wirefinder<br />
Wirefinder<br />
Position
Running Tools<br />
Otis ® X ® <strong>and</strong> R ® Running Tools<br />
Otis® X® <strong>and</strong> R® running tools are used<br />
to set Otis X, XN®, R, RN®, <strong>and</strong> RQ<br />
lock m<strong>and</strong>rels in their respective Otis<br />
l<strong>and</strong>ing nipples. These tools are<br />
designed with locator dogs, serving to<br />
locate the proper l<strong>and</strong>ing nipple <strong>and</strong><br />
positioning the lock m<strong>and</strong>rel before<br />
locating <strong>and</strong> locking. By selecting the<br />
position of the running tool, the lock<br />
m<strong>and</strong>rel keys may be placed in the<br />
locating or retracted position.<br />
Otis RXN Running Tools<br />
Otis RXN running tools set Otis X, XN,<br />
R, RN, RPT®, <strong>and</strong> RQ lock m<strong>and</strong>rels in<br />
their respective l<strong>and</strong>ing nipples. This<br />
tool is generally used for installing<br />
wireline-retrievable subsurface valves<br />
in the uppermost l<strong>and</strong>ing nipple in<br />
staggered bore nipples such as RPT.<br />
With this tool, the lock m<strong>and</strong>rel may be<br />
run with the keys in the control or<br />
locating positions. The lock m<strong>and</strong>rel<br />
keys or no-go serve to locate the nipple<br />
rather than the dogs on the running<br />
tool. When a non-no-go lock is being<br />
run, the keys must be run in the<br />
locating position <strong>and</strong> the lock must be<br />
set in the first nipple in the bore of that<br />
lock size. The tool gives a positive<br />
indication when the lock is fully set.<br />
Otis SAFETYSET ® Running Tools<br />
Otis SAFETYSET® running tools are<br />
used to set <strong>Halliburton</strong> surfacecontrolled,<br />
wireline-retrievable safety<br />
valves on Otis RP <strong>and</strong> RQ lock<br />
m<strong>and</strong>rels. Two independent conditions<br />
must exist in sequence before the<br />
running tool will release the valve <strong>and</strong><br />
lock. First, the SCSSV must be<br />
pressured open to activate the running<br />
tool. Second, only when the locking<br />
sleeve is moved upward into its locked<br />
position will the running tool release.<br />
A running tool retrieved to the surface<br />
without the lock <strong>and</strong> valve indicates a<br />
functional valve securely locked in the<br />
l<strong>and</strong>ing nipple.<br />
Otis UP Running Tool<br />
An Otis UP running tool is also<br />
available for running SAFETYSET lock<br />
m<strong>and</strong>rels <strong>and</strong> subsurface safety valves,<br />
which utilize staggered sealbores. The<br />
UP running tool is entirely mechanical<br />
<strong>and</strong> does not require control line<br />
pressure to activate.<br />
Otis MR Running Tools<br />
Otis MR running tools are used to run<br />
Otis XNS <strong>and</strong> RNS soft set bomb<br />
hangers. This running tool is designed<br />
to carry weight exceeding the 140-lb<br />
(63.50 kg) weight limit of hydraulic<br />
running tools because no preset force<br />
needs to be overcome.<br />
The lugs of the running tool hold the<br />
fish neck of the bomb hanger during<br />
the running of the bombs. The lugs are<br />
held in the exp<strong>and</strong>ed position by the<br />
core in the fully down position. When<br />
the bomb hanger locks into the nipple<br />
profile, the lock moves upward,<br />
pushing the core up by means of the<br />
core extension. Once the core is pushed<br />
up, the lock-out lug can then be pushed<br />
into the core recess by the leaf spring,<br />
thus locking the core in the up position.<br />
In the up position, the core no longer<br />
holds the lugs out <strong>and</strong> the running tool<br />
is disengaged from the hanger. The<br />
bomb hanger <strong>and</strong> pressure gauges are<br />
left suspended in the well.<br />
7-8 Slickline Service Equipment<br />
HAL8516<br />
Otis® RXN<br />
Running Tool<br />
HAL8518<br />
Otis®<br />
SAFETYSET®<br />
Running Tool<br />
HAL14029<br />
HAL8517<br />
Otis® UP<br />
Running Tool<br />
Otis® X® or R®<br />
Running Tool<br />
HAL8519<br />
Otis® MR<br />
Running Tool
Pulling Tools<br />
Internal Fishing Necks<br />
Otis® GS pulling tools are used during wireline operations to<br />
unlock <strong>and</strong> pull a variety of subsurface controls with internal<br />
fishing necks, such as an Otis G pack-off assembly. Designed<br />
to shear with a jarring down action, this pulling tool is used<br />
where excessive jarring upward is necessary to retrieve<br />
subsurface flow controls. In the running position, the dogs<br />
are designed to seat <strong>and</strong> lock in the internal recess of the<br />
m<strong>and</strong>rel being retrieved. If the device cannot be retrieved by<br />
upward jarring, the GS pulling tool can be released by jarring<br />
down which shears the pin to allow the pulling tool <strong>and</strong><br />
toolstring to be removed from the well. With this tool being a<br />
shear-down-to-release, it can be used in many cases as a<br />
running tool for certain devices.<br />
Otis GR pulling tools are used during wireline operations to<br />
unlock <strong>and</strong> pull a variety of subsurface controls with internal<br />
fishing necks, including: Otis D bridge plugs, Otis X® <strong>and</strong> R®<br />
lock m<strong>and</strong>rels, Otis D m<strong>and</strong>rels, <strong>and</strong> Otis D collar stops.<br />
Designed to shear with a jarring up action, this pulling tool is<br />
used during routine wireline operations on controls when<br />
shear-down is not possible. The Otis GR pulling tool is<br />
assembled by incorporating an Otis GS pulling tool with an<br />
Otis GU shear-up adapter.<br />
External Fishing Necks<br />
Otis S pulling tools are designed for jobs<br />
in which extensive upward jarring is<br />
required to pull a bottomhole control.<br />
This tool is designed to pull any<br />
subsurface equipment with an external<br />
fishing neck. The core is manufactured in<br />
various lengths <strong>and</strong> may be changed in<br />
the field to accommodate the fishing<br />
necks of various controls. These are<br />
referred to as SS, SB, or SJ. The tool is<br />
designed to shear <strong>and</strong> release by<br />
downward jarring. With this feature, the<br />
tool may also be used as a running tool to<br />
run collar stops, pack-off anchor stops,<br />
<strong>and</strong> various other <strong>Halliburton</strong> tools.<br />
Note: When used as a running tool, the<br />
core must be long enough to allow for<br />
upward travel after shearing the pin<br />
before the skirt is stopped by the<br />
equipment being run. It is this action<br />
that permits complete release of the running tool.<br />
HAL8523<br />
Otis® S Pulling Tool<br />
Fishing Neck<br />
Shear Pin<br />
Dowel Pin<br />
Core Nut<br />
Otis R pulling tools are designed for jobs<br />
in which extensive downward jarring is<br />
required. Tools use upward jarring to<br />
release when necessary. Dogs in the R<br />
pulling tool engage the fishing neck of the<br />
device to allow it to shear with upward<br />
jarring. The R pulling tool can be<br />
modified as follows:<br />
Otis RB pulling tool (R body with a<br />
B core) pulls Otis B, C, <strong>and</strong> W lock<br />
m<strong>and</strong>rel assemblies <strong>and</strong> m<strong>and</strong>rel<br />
assemblies with full relative motion<br />
Otis RS pulling tool (R body with<br />
S core) pulls <strong>Halliburton</strong> S m<strong>and</strong>rel<br />
assemblies<br />
Otis RJ pulling tool (R body with J<br />
core) pulls all controls that do not<br />
have full relative motion<br />
Shear Pin<br />
Fishing<br />
Neck<br />
Shear Pin<br />
Cylinder<br />
Spring<br />
Spring<br />
Retainer<br />
Dog Spring<br />
Dog Retainer<br />
Cylinder<br />
Slickline Service Equipment 7-9<br />
HAL8520<br />
Otis® GU Shear<br />
Up Adapter<br />
HAL8521<br />
Otis® GS Pulling<br />
Tool Shear Down<br />
Dogs<br />
Core<br />
HAL8544<br />
HAL8522<br />
Otis® GR<br />
Pulling Tool<br />
Shear Up<br />
Otis® R® <strong>Wireline</strong><br />
Pulling Tool
Plugs For Wells Without L<strong>and</strong>ing Nipples<br />
Monolock ® Plug<br />
The <strong>Halliburton</strong> Monolock® plug is<br />
designed to be set anywhere in a given<br />
size of tubing, casing, or liner. The<br />
Monolock plug differs from a<br />
conventional lock m<strong>and</strong>rel because it<br />
does not require either a profile or<br />
sealbore in the tubing string <strong>and</strong> is<br />
retained in its set position by slips<br />
rather than keys. The Monolock plug<br />
may be used in association with the<br />
<strong>Halliburton</strong> full bore nipple system<br />
or any other selective or nipple <strong>and</strong><br />
lock system.<br />
The plug is set <strong>and</strong> retrieved with<br />
<strong>Halliburton</strong>’s DPU® running <strong>and</strong><br />
retrieving tools, which can be run on<br />
slickline, braided line, or coiled tubing.<br />
When used for plugging applications,<br />
the plug is designed to withst<strong>and</strong><br />
differential pressure of up to 10,000 psi<br />
(690 bar) from either direction.<br />
Applications<br />
As a retrievable bridge plug placed<br />
anywhere in the tubing string<br />
Can be adapted to install BHP<br />
gauges <strong>and</strong> other flow control<br />
devices<br />
Plug tubing below hanger for well<br />
repairs<br />
Features<br />
Pressure ratings up to 10,000 psi<br />
(690 bar)<br />
Requires no l<strong>and</strong>ing receptacle<br />
Seals against pipe ID<br />
Slip-type anchor system<br />
Element is retracted during retrieval<br />
Belleville spring energy storage<br />
system provides positive sealing<br />
during pressure reversals<br />
Can be installed <strong>and</strong> retrieved<br />
through restrictions<br />
Run <strong>and</strong> retrieved on same DPU<br />
unit<br />
Run on slickline, braided line, or<br />
coiled tubing<br />
Element located above slips,<br />
preventing any debris accumulation<br />
around slip area<br />
Equalizing feature provided in<br />
st<strong>and</strong>ard assembly<br />
Barrel-slip design provides<br />
maximum slip engagement while<br />
minimizing tubing deformation<br />
Benefits<br />
Can be set anywhere in tubing,<br />
casing, or liner<br />
Quick running <strong>and</strong> retrieval<br />
Use of slickline rather than<br />
conductor line lowers installation<br />
<strong>and</strong> retrieval costs<br />
Redressable in field, reducing<br />
downtime<br />
Because element returns to original<br />
shape, assembly can be recovered<br />
back through restrictions<br />
Slip configuration ensures<br />
centralized setting of the lock even<br />
in high-angle or horizontal wells<br />
Provides same reliability as<br />
production packers<br />
Slip design minimizes tubing<br />
deformation<br />
7-10 Slickline Service Equipment<br />
HAL10466<br />
Monolock® Plug
Test Tools<br />
Otis® selective test tools are used to test tubing, locate leaks,<br />
or set hydraulic-set packers. Designed to hold pressure from<br />
above, selective test tools may be set in compatible Otis X®,<br />
XN®, R®, or RN® l<strong>and</strong>ing nipples in the tubing string. With<br />
the keys retracted, the tool is run to a point below the desired<br />
nipple. Pulling up through the nipple releases the locking<br />
keys to set the tool with downward motion. Pressure from<br />
above may then be applied.<br />
Features<br />
Designed for high working pressure<br />
Located in the lowest nipples first, these tools are then<br />
moved up the tubing <strong>and</strong> set in sequential nipples until a<br />
leak is not detected, thus reducing wireline trips<br />
Otis Non-Selective Test Tools<br />
Otis non-selective test tools are designed to test the tubing<br />
string, set hydraulic packers, <strong>and</strong> protect lower zones when<br />
circulating through a Sliding Side-Door® circulating device<br />
or producing a zone above the lowermost zone. Designed to<br />
hold pressure from above only by employing the use of a<br />
drop valve equalizing assembly, the non-selective test tools<br />
l<strong>and</strong> in no-go l<strong>and</strong>ing nipples with compatible packing<br />
bores. When l<strong>and</strong>ed in the l<strong>and</strong>ing nipple, pressure from<br />
above is sealed by the drop, seal ring, <strong>and</strong> v-packing. In order<br />
to retrieve by wireline, the drop is moved off seat with a<br />
pulling tool. This equalizes the pressure across the test tool,<br />
allowing it to be retrieved.<br />
Features<br />
Ease of running, setting, <strong>and</strong> retrieving<br />
No-go OD on bottom of tool for positive location in<br />
l<strong>and</strong>ing nipple<br />
May be pumped into the well<br />
Designed for high-pressure ratings<br />
Slickline Service Equipment 7-11<br />
HAL8524<br />
Otis® Non-Selective<br />
Test Tool<br />
HAL8525<br />
Otis® Selective<br />
Test Tool
Positioning Tools<br />
Otis ® BO Selective Positioning Tools<br />
Otis® BO selective positioning tools are used to move the<br />
inner sleeve to its open or closed position in Sliding<br />
Side-Door® circulating devices.<br />
Note: The Otis B selective positioning tool is not to be used<br />
for shifting Otis XXO or RRO surface-controlled safety valve<br />
nipples. For these nipples, use the Otis XL or RL shifting tool.<br />
The positioning tool engages the recess in the upper<br />
(or lower) end of the inner sleeve to permit the sleeve to be<br />
shifted by a jarring action. The tool is designed to release<br />
itself only after the sleeve reaches its fully open or closed<br />
position. This automatic-releasing feature incorporates a<br />
releasing profile on the key itself that acts to compress the key<br />
spring <strong>and</strong> release the positioning tool. A shear pin is an<br />
added feature designed to release the tool in the event well<br />
conditions make it impossible to shift the sleeve.<br />
A set of positive keys is available for this tool to permit<br />
upward movement of the inner sleeve of one among several<br />
Sliding Side-Door circulating devices in one wellbore. These<br />
keys do not have a releasing profile. The positioning tool pin<br />
must be sheared to release.<br />
Note: The Otis BO selective positioning tool will not pass<br />
through position number 1 of Otis S l<strong>and</strong>ing nipples.<br />
Otis BO selective positioning tools are designed to selectively<br />
position Sliding Side-Door inner sleeves only to the down<br />
position. These tools are designed so that one sleeve can be<br />
shifted to the down position at any level in the tubing string<br />
without shifting any other sleeve.<br />
This positioning tool is designed with dogs that serve to<br />
locate the proper Sliding Side-Door circulating device <strong>and</strong><br />
release the spring-loaded keys to engage the profile in the<br />
inner sleeve. The tool is designed to release itself only after<br />
the sleeve reaches the full-down position. This automaticrelease<br />
feature incorporates a releasing profile on the key<br />
that acts to compress the key spring <strong>and</strong> release the<br />
positioning tool. The tool can then be raised to the next<br />
Sliding Side-Door circulating device to position its sleeve<br />
down or return to the surface.<br />
7-12 Slickline Service Equipment<br />
HAL8526<br />
Otis® BO Selective<br />
Positioning Tool<br />
HAL8527<br />
Otis® BP Selective<br />
Positioning Tool
Tubing Perforators <strong>and</strong> Bailers<br />
Otis® A tubing perforators are mechanically operated <strong>and</strong><br />
can be used with slickline (under pressure) to perforate both<br />
st<strong>and</strong>ard <strong>and</strong> heavyweight tubing.<br />
Applications<br />
To provide access to casing annulus to circulate or kill a<br />
well<br />
To bring in additional productive zones<br />
To permit production through tail pipe that has been<br />
plugged <strong>and</strong> cannot be opened by regular methods<br />
Features<br />
No explosives used, minimizing the possibility of<br />
perforating the casing<br />
Safety-release mechanism designed to permit removing<br />
perforator without perforating<br />
Greater tubing penetration<br />
Perforator designed to retract the punch <strong>and</strong> release<br />
automatically after perforating<br />
Service performed by <strong>Halliburton</strong>-trained personnel<br />
Otis M s<strong>and</strong> pump bailers may be used to remove a s<strong>and</strong><br />
bridge if one is encountered during normal wireline<br />
operations. The s<strong>and</strong> bailer consists of a piston encased in an<br />
outer cylinder. By working the wireline in the same manner<br />
as used to set certain subsurface controls (lightly jarring up<br />
<strong>and</strong> down), the bailer acts to pull s<strong>and</strong> into the cylinder to<br />
remove the s<strong>and</strong> bridge. An assortment of bailer bottoms is<br />
available:<br />
Flat bottom for soft, easy-to-bail s<strong>and</strong><br />
Chisel bottom for hard-packed s<strong>and</strong><br />
Flapper bottom for bailing metal particles that are too<br />
large to pass the ball <strong>and</strong> seat<br />
Otis B hydrostatic bailers are designed for use when the<br />
substance to be bailed cannot be removed by a pump-type<br />
bailer. This is sometimes the case when small metallic<br />
particles become lodged on top of the locking m<strong>and</strong>rel dogs<br />
of a subsurface flow control.<br />
The Otis B hydrostatic bailer is sealed at the surface <strong>and</strong> run<br />
into the tubing bore with the internal bailer chamber at<br />
atmospheric pressure. When the bailer reaches the object to<br />
be bailed, a few downward strokes of the wireline jars act to<br />
shear a small sealing disc <strong>and</strong> admit the well pressure <strong>and</strong>/or<br />
hydrostatic head (as well as the junk) into the bailer cylinder.<br />
A ball check valve acts to contain the junk in addition to the<br />
well pressure until the bailer is retrieved. For large pieces of<br />
junk, a flapper bottom <strong>and</strong> junk basket are available.<br />
Note: The internal chamber pressure should always be bled<br />
off through the bailer release valve before the bailer bottom is<br />
broken off at surface.<br />
Slickline Service Equipment 7-13<br />
HAL8530<br />
Otis® A Tubing<br />
Perforator<br />
HAL8531<br />
Otis® M<br />
S<strong>and</strong> Pump Bailer<br />
HAL8532<br />
Otis® B<br />
Hydrostatic Bailer
Slickline Skid Units <strong>and</strong> Trucks<br />
<strong>Halliburton</strong> designs <strong>and</strong> manufactures top quality skid-base<br />
units for offshore operations <strong>and</strong> trucks for l<strong>and</strong> operations.<br />
The units are known worldwide for their user-focused<br />
design, providing the right mix of operator-friendly<br />
HAL22812<br />
HAL22811<br />
Offshore Three-Piece<br />
Skid Unit<br />
T800 Slickline Crane Truck<br />
HAL22808<br />
HAL22810<br />
components to make both specialized <strong>and</strong> st<strong>and</strong>ard<br />
operations more productive. For more detailed information,<br />
please contact your local <strong>Halliburton</strong> representative.<br />
Slickline Container Unit<br />
Stainless Steel Skid Unit<br />
7-14 Slickline Service Equipment<br />
HAL22809
Surface Service Equipment<br />
<strong>Halliburton</strong>’s wellhead pressure control equipment<br />
provides for a safe <strong>and</strong> highly productive service operation.<br />
Unmatched equipment quality backed by available<br />
extensive training <strong>and</strong> maintenance instruction has made<br />
HAL22757<br />
Options:<br />
Lubricator<br />
Safety Valve<br />
Pin End Assembly<br />
Options:<br />
• Slickline Grease<br />
Head<br />
Liquid Chamber<br />
Lubricator Control<br />
(Purge) Valve<br />
Hydraulic Stuffing Box<br />
(16-in. Sheave)<br />
Quick Union<br />
Upper Lubricator<br />
Section<br />
Quick Union<br />
Middle Lubricator<br />
Section<br />
Lubricator Pick<br />
Up Clamp<br />
Quick Union<br />
Lower Lubricator<br />
Section<br />
Option:<br />
Pump-In Sub<br />
Quick Union<br />
<strong>Wireline</strong> Valve<br />
Single<br />
(Manual or Hydraulic)<br />
Flanged Tree<br />
Connection<br />
<strong>Halliburton</strong> the industry’s premier provider of this type of<br />
equipment <strong>and</strong> services. For more detailed information,<br />
please contact your local <strong>Halliburton</strong> representative.<br />
Options:<br />
<strong>Wireline</strong> Valve<br />
Dual (Manual or Hydraulic)<br />
<strong>Wireline</strong> Valve<br />
Triple (Manual or Hydraulic)<br />
Slickline Grease Head<br />
Liquid Chamber<br />
Dual <strong>Wireline</strong> Valve<br />
(Manual or Hydraulic)<br />
Triple <strong>Wireline</strong> Valve<br />
(Manual or Hydraulic)<br />
Slickline Service Equipment 7-15<br />
HAL22755<br />
HAL22756<br />
HAL22754<br />
HAL22753
Advanced ® Slickline <strong>Services</strong><br />
Highly developed measurement <strong>and</strong> innovative downhole<br />
tools provide low-cost slickline solutions for well<br />
interventions.<br />
<strong>Halliburton</strong> Advanced® slickline services let you set <strong>and</strong><br />
retrieve packers, plugs, <strong>and</strong> monobore flow controls, <strong>and</strong><br />
perforate, cut casing, <strong>and</strong> tubing–all with depth accuracy<br />
comparable to electric line with the efficiency of slickline.<br />
<strong>Halliburton</strong>’s innovative slickline technology produces depth<br />
measurements so accurate you can now use slickline<br />
procedures for many services traditionally reserved for<br />
electric line operations. Procedure for procedure, when<br />
compared to electric line, <strong>Halliburton</strong>'s new slickline<br />
technology substantially lowers your total cost.<br />
Key developments make this revolutionary advance in<br />
slickline utility possible:<br />
An advanced measurement system that makes slickline<br />
depth readings comparable to electric line depth<br />
readings<br />
A slickline collar locator that pinpoints tubing or casing<br />
collars<br />
A downhole power unit that eliminates the need for<br />
explosives to set packers <strong>and</strong> plugs<br />
An electronic triggering device that fires perforating <strong>and</strong><br />
cutting charges<br />
A data/job logger that produces real-time slickline collar<br />
logs or customer job summary<br />
A wire inspection device that detects abnormalities in<br />
slickline to facilitate wire management <strong>and</strong> reduce<br />
premature failures<br />
Unprecedented Slickline Accuracy<br />
<strong>Halliburton</strong>'s Advanced Measurement System (AMS) uses<br />
microprocessor technology to take the guesswork out of<br />
slickline depth measurements. Yes, we still count wheel turns.<br />
But, the processor not only counts wheel turns, it also<br />
instantly <strong>and</strong> continuously adjusts for the effect of ambient<br />
temperature on counter wheel size <strong>and</strong> for tension-caused<br />
line stretch measured with an electronic load sensor. Depth,<br />
tension, <strong>and</strong> line speed are logged <strong>and</strong> a hard copy printed in<br />
real time, guiding the operator <strong>and</strong> providing a permanent<br />
job record.<br />
Correlate to the Original Log to Identify Collar Locations<br />
<strong>Halliburton</strong>'s exclusive slickline collar locator further<br />
enhances data accuracy. As it passes a tubing or casing collar,<br />
it increases line tension. The tension spikes are recorded in<br />
real time on the permanent job log so the operator always<br />
knows the precise tool location in relation to the tubing or<br />
casing collars.<br />
Set Packers <strong>and</strong> Plugs Without Explosives<br />
The remarkable <strong>Halliburton</strong> DPU® downhole power unit<br />
eliminates the need to use explosive charges to set packers<br />
<strong>and</strong> plugs. The slow controlled force provided by an<br />
electromechanical powertrain improves setting<br />
performance for downhole equipment, such as packers,<br />
where improved element compression <strong>and</strong> a more uniform<br />
slip set are obtained.<br />
7-16 Slickline Service Equipment
CollarTrak ®<br />
Slickline Collar<br />
Locator<br />
DPU ®<br />
Downhole<br />
Power Unit<br />
LineTrak ® Inspection Device<br />
Bridge Plug<br />
SmartETD ®<br />
System<br />
JobTrak ®<br />
Data Logger<br />
Advanced ®<br />
Slickline<br />
Service Unit<br />
<strong>Perforating</strong> Gun<br />
Advanced® Slickline Service Tools<br />
Advanced Measuring System (AMS)<br />
Memory Production Logging<br />
CCL/Gamma Ray<br />
Pressure<br />
Temperature<br />
Capacitance Water Holdup<br />
Filled Density (Differential Pressure)<br />
Fullbore Spinner <strong>and</strong> Continuous<br />
Monolock ® Plug Packer Perforator<br />
Slickline Service Equipment 7-17
<strong>Perforating</strong> <strong>and</strong> Cutting <strong>Services</strong> Performed with Slickline<br />
The <strong>Halliburton</strong> electronic triggering device employs<br />
slickline to run <strong>and</strong> fire perforating <strong>and</strong> cutting charges when<br />
explosives are a requirement. The triggering device also can<br />
be used to fire explosive-activated tools used to set plugs <strong>and</strong><br />
packers. The device's redundant safety system prevents<br />
premature firing.<br />
Produce a Permanent Job Record<br />
Data recorded through the job logger can either be a printed<br />
hardcopy or stored to floppy disc as a permanent well file.<br />
The data can also be merged with data from downhole<br />
memory tool surveys to produce API quality production well<br />
logs for diagnostic or flow analysis.<br />
Even More Built in Reliability<br />
<strong>Halliburton</strong>'s new wire inspection device <strong>and</strong> wire<br />
management software has prevented fishing trips <strong>and</strong> has<br />
greatly reduced lost production time caused by slickline<br />
failure. The device can be used for periodic electronic<br />
inspection to detect line abnormalities.<br />
The wire management software tracks wire usage <strong>and</strong><br />
provides a permanent record of each line's job history, when<br />
utilizing AMS. The software provides a basis for predicting<br />
wire failures due to normal, job-related stresses, <strong>and</strong><br />
exposure to hostile well environments.<br />
The state-of-the-art Advanced® slickline service system<br />
offered by <strong>Halliburton</strong> provides the most efficient means for<br />
precise depth correlation, setting plugs <strong>and</strong> packers,<br />
perforating, <strong>and</strong> producing high quality memory production<br />
logs.<br />
Advanced ® Slickline Service System<br />
This system provides services traditionally performed by<br />
e-line services, but with slickline.<br />
Save With <strong>Halliburton</strong> Advanced Slickline <strong>Services</strong><br />
You can substantially save on your electric line costs for<br />
comparable services with <strong>Halliburton</strong>'s Advanced slickline<br />
technology. And the <strong>Halliburton</strong> wire inspection device in<br />
conjunction with wire management software can cut the<br />
costs of traditional slickline services by significantly reducing<br />
the potential for line breaks.<br />
7-18 Slickline Service Equipment
DPU ® Downhole Power Unit<br />
<strong>Halliburton</strong>’s DPU® downhole power unit is an electromechanical<br />
downhole electric power supply device that<br />
produces a linear force for setting packers using downhole<br />
electric power. The tool is self-contained with a battery unit<br />
<strong>and</strong> an electrical timer to start the setting operation. The unit<br />
consists of three functioning sections: the pressure sensing<br />
actuator, the power source, <strong>and</strong> the linear drive section.<br />
The slickline version of the DPU unit uses batteries to<br />
provide the energy to the motor <strong>and</strong> timing circuits. An<br />
electric line version without the timer, circuits, <strong>and</strong> batteries<br />
is also available.<br />
Note: Both slickline <strong>and</strong> e-line DPU units include conversion<br />
kits to allow the use of existing Baker setting adapter kits.<br />
The DPU unit <strong>and</strong> attached subsurface device are run into<br />
the well on slickline or braided line. The timer initiates the<br />
operation. The setting motion is gradual <strong>and</strong> controlled<br />
(about 0.7 in./min) allowing the sealing element to conform<br />
against the casing/tubing wall <strong>and</strong> the slips to fully engage.<br />
The controlled setting motion allows the sealing element to<br />
be fully compressed. Once the setting force is reached, the<br />
DPU unit shears loose from the subsurface device <strong>and</strong> is free<br />
for removal from the well. The DPU unit is designed to help<br />
set <strong>and</strong> allow for dependable operation of downhole flow<br />
control devices, reduce well completion costs, <strong>and</strong> improve<br />
safety at the wellsite.<br />
Applications<br />
Sets <strong>and</strong> Retrieves:<br />
Packers<br />
Bridge plugs<br />
Whipstocks<br />
Monolock® devices<br />
Subsea tree plugs<br />
Sets:<br />
Cement retainers<br />
Sump packers<br />
HE3® retrievable bridge plugs<br />
BB wireline-retrievable packers<br />
Perforates:<br />
Tubing<br />
Casing<br />
Shifts:<br />
Sliding Side-Door® circulation/production devices<br />
Internal control valves<br />
Releasing mechanisms/sleeves<br />
Slickline Service Equipment 7-19<br />
HAL14000<br />
DPU® Downhole<br />
Power Unit
Features<br />
Equipped with a timer/accelerometer/pressure actuation<br />
system to ensure tool setting at the proper time <strong>and</strong><br />
depth<br />
Batteries for self-contained operation<br />
Slickline, e-line, or coiled tubing operation<br />
Sets <strong>and</strong> retrieves tools with optimal setting force<br />
Reduced cost for setting packers <strong>and</strong> bridge plugs using<br />
traditional electric line<br />
Non-explosive operation improves safety<br />
Eliminates need for electric wireline<br />
Dependable operation<br />
Positive setting of slips <strong>and</strong> elements<br />
Optimized operating speed<br />
7-20 Slickline Service Equipment
Max OD<br />
in. (mm)<br />
1.70<br />
(43.2)<br />
2.51<br />
(63.75)<br />
3.59<br />
(91.19)<br />
Max OD<br />
in. (mm)<br />
1.70<br />
(43.2)<br />
2.51<br />
(63.75)<br />
3.81<br />
(96.77)<br />
Max Shear<br />
Force<br />
lbf (N)<br />
15,000<br />
(66 720)<br />
30,000<br />
(133 440)<br />
50,000<br />
(222 400)<br />
60,000<br />
(266 880)<br />
Max Shear<br />
Force<br />
lbf (N)<br />
15,000<br />
(66 720)<br />
30,000<br />
(133 440)<br />
60,000<br />
(266 880)<br />
Slickline DPU ® System Specifications<br />
Voltage Amps<br />
27 2<br />
36 4<br />
30 5<br />
48 2<br />
Max<br />
Temperature<br />
°F (°C)<br />
300<br />
(148)<br />
300<br />
(148)<br />
250<br />
(121)<br />
329<br />
(165)<br />
E-Line DPU System Specifications<br />
Voltage Amps<br />
50 0.6<br />
115 0.6<br />
200 0.75<br />
Max<br />
Temperature<br />
°F (°C)<br />
400<br />
(204)<br />
400<br />
(204)<br />
400<br />
(204)<br />
Max Pressure<br />
psi (bar)<br />
15,000<br />
(1034.5)<br />
15,000<br />
(1034.5)<br />
10,000<br />
(689.4)<br />
10,000<br />
(689.4)<br />
Max Pressure<br />
psi (bar)<br />
15,000<br />
(1034.5)<br />
15,000<br />
(1034.5)<br />
20,000<br />
(1378)<br />
Max Effective<br />
Stroke<br />
in. (mm)<br />
9<br />
(229)<br />
8.5<br />
(216)<br />
36<br />
(914)<br />
8.75<br />
(222)<br />
Max Effective<br />
Stroke<br />
in. (mm)<br />
9<br />
(229)<br />
8.5<br />
(216)<br />
8.75<br />
(222)<br />
Slickline Service Equipment 7-21
DPU ® Tubing Punch<br />
The DPU® tubing punch can help cut your costs for<br />
perforating the tubing. Coupled with the Monolock®<br />
plugging device, the DPU tubing punch provides an effective<br />
<strong>and</strong> dependable solution for well (kill) workover operations.<br />
Features<br />
Can reduce the cost for perforating tubing<br />
Reduces rig time by minimizing misruns with other<br />
mechanical perforators<br />
No extensive jarring to achieve a hole<br />
Eliminates the need for electric wireline <strong>and</strong> an explosive<br />
soft shot perforating service. The DPU tubing punch can<br />
be run on slickline, braided line, or coiled tubing. This<br />
means it offers the economy of slickline <strong>and</strong> the<br />
versatility to meet operational requirements<br />
Improves safety with its non-explosive operation by<br />
eliminating transportation <strong>and</strong> h<strong>and</strong>ling of explosives<br />
<strong>and</strong> by not requiring explosive-trained personnel<br />
Offers proven, dependable operation of the punch<br />
Equipped with a timer/accelerometer/pressure actuation<br />
system for precise control<br />
HAL23160<br />
7-22 Slickline Service Equipment<br />
HAL23161
Size<br />
in. (mm)<br />
2.50<br />
(64)<br />
3.66<br />
(93)<br />
1.69<br />
(43)<br />
CollarTrak ® Slickline Collar Locator<br />
The <strong>Halliburton</strong> CollarTrak® slickline collar locator consists<br />
of a st<strong>and</strong>ard electric line collar locator, an electronic subassembly,<br />
<strong>and</strong> a magnet/drag sub-assembly. When the collar<br />
locator senses a tubing or casing collar, it signals the<br />
electronic sub-assembly, which instantaneously activates<br />
magnets in the magnet/drag assembly. The magnets increase<br />
frictional engagement to the pipe wall, creating a brief but<br />
significant increase in line tension.<br />
<strong>Halliburton</strong>'s advanced measurement system detects the<br />
tension increase <strong>and</strong> sends the data signals to the data/job<br />
logger, which records it as a well-defined spike on the log.<br />
The advanced measurement system automatically <strong>and</strong><br />
continuously compensates for line stretch, assuring<br />
log accuracy.<br />
The tool, which is powered by alkaline batteries, locates<br />
collars in up to 13 chrome pipe <strong>and</strong> in flush-joint tubing.<br />
Tubing<br />
or<br />
Casing<br />
Size in.<br />
3 1/2-<br />
41/2<br />
5 1/2-<br />
7 5/8<br />
2 3/8-<br />
2 7/8<br />
Max OD<br />
Magnets<br />
Collapsed<br />
in. (mm)<br />
2.50<br />
(64)<br />
3.66<br />
(93)<br />
1.69<br />
(43)<br />
CollarTrak® Slickline Collar Locator<br />
Slickline Collar Locator (SLCL) (with Power Pack) Specifications<br />
Max OD<br />
Magnets<br />
Exp<strong>and</strong>ed<br />
in. (mm)<br />
3.85<br />
(98)<br />
5.50<br />
(140)<br />
3.06<br />
(77)<br />
All sizes are alloy material <strong>and</strong> have three magnets.<br />
Optional<br />
Larger<br />
Magnet<br />
Housing<br />
Max OD Larger<br />
Magnet Housing<br />
Collapsed<br />
in. (mm)<br />
Slickline Service Equipment 7-23<br />
HAL8887<br />
Max OD Larger<br />
Magnet Housing<br />
Exp<strong>and</strong>ed<br />
in. (mm)<br />
Max<br />
Operating<br />
Pressure<br />
psi<br />
Max<br />
Operating<br />
Temp.<br />
°F<br />
No N/A N/A 15,000 300<br />
Yes<br />
5.70<br />
(145)<br />
7.50<br />
(191)<br />
10,000 250<br />
No N/A N/A 15,000 300<br />
Overall<br />
Length<br />
in. (mm)<br />
95.3<br />
(2.421)<br />
69.8<br />
(1.773)<br />
34.12<br />
(.86)<br />
Power<br />
Source<br />
“AA” size<br />
Batteries<br />
“C” size<br />
Batteries<br />
“AA” size<br />
Batteries<br />
Top<br />
Connection<br />
1 5/16-in. -<br />
10UNS pin<br />
1 1/16 in. -<br />
10UNS pin<br />
1 5/16 in. -<br />
10UNS pin<br />
Bottom Tool<br />
Connection<br />
1 5/16-in. -<br />
10UNS box<br />
1 1/16 -<br />
10UNS box<br />
15/16 in. -<br />
10UNS box
HAL8356<br />
Electronic Depth<br />
Measurement System<br />
Combination Depth Counter<br />
<strong>and</strong> Line Tension Sensors<br />
(Input to Electronic Depth<br />
Measurement System)<br />
Slickline<br />
Collar<br />
Locator<br />
Downhole<br />
Power Unit<br />
Slickline Collar<br />
Log<br />
Bridge<br />
Plug or<br />
packer<br />
Slickline Service Unit<br />
Data/Job Logger<br />
(Portable)<br />
7-24 Slickline Service Equipment<br />
<strong>Halliburton</strong> Job Logger<br />
JOB ENDED ( DATE: May, 02 1995 TIME: 15:04:39 )<br />
MAXIMUM ( DEPTH: 1352.5 m TENSION : 123 DNs LINE SPEED : 238.8 m/min<br />
)<br />
COMMENTS : TOOL BOX SAFETY MEETING<br />
RIH FLOWING DUMMY AT 1353M.<br />
RIH FLOWING SURVEY MAKE 5 MIN STOP 250M 423M 453M 746M<br />
766M 984M 1104M 1152M 1172M 1282M 1302 1343M 15MIN STOP<br />
CASSING PRESS 4000KPA<br />
6100<br />
6200<br />
6000<br />
Line Speed<br />
Casing<br />
Collar<br />
Location
Advanced Measurement System (AMS)<br />
The electronic advanced measurement system (AMS)<br />
measures tension <strong>and</strong> depth, compensates for wire stretch<br />
<strong>and</strong> temperature effects on the measuring wheel, <strong>and</strong> reports<br />
a corrected depth reading. This model of the AMS system is<br />
designed to be mounted inside a wireline operator cabin.<br />
Other features also help improve the quality of a service job.<br />
A differential load indicator indicates small changes in<br />
pickup weight. Digital displays can be switched between<br />
English <strong>and</strong> metric measurements at any time. The<br />
approaching surface alarm warns the operator as the tools<br />
near the surface. The excessive tension function works with<br />
the hydraulic system to limit the maximum line tension to an<br />
adjustable preset value. The system allows the operator to<br />
input a “rig-up angle” for accurate line tension readings.<br />
When used with a <strong>Halliburton</strong> two-wheel counter with a<br />
“universal” measuring wheel, the AMS gives accurate depth<br />
readings for any size wire, in English or metric, without<br />
changing wheels.<br />
This model has digital <strong>and</strong> analog displays with switch input<br />
controls <strong>and</strong> RS-232 output for data acquisition with a<br />
laptop computer.<br />
Panel AMS will not work with IS (Class 1 Division 2)<br />
counter. This system requires an electronic strain gauge load<br />
sensor <strong>and</strong> an optical encoder.<br />
St<strong>and</strong>ard Mounted Equipment<br />
Automatic depth adjustment<br />
Line tension adjustment<br />
Depth offset adjustment<br />
Ambient temperature correction<br />
Analog line tension display<br />
Analog differential line tension display<br />
Digital line tension display<br />
Digital line depth display<br />
Digital line speed display<br />
RS-232 serial port output for corrected depth, line speed,<br />
line tension, units of measurement, <strong>and</strong> time<br />
Advanced Measurement System<br />
Slickline Service Equipment 7-25<br />
HAL8890
Electronic Advanced Measurement System (Portable)<br />
This portable model has a flat screen display, keypad<br />
functional inputs, <strong>and</strong> extended RAM for data storage.<br />
A RS-232 serial port is provided for real-time data retrieval.<br />
This system requires an electronic strain gauge, load sensor,<br />
<strong>and</strong> an optical encoder. The portable unit is available for<br />
st<strong>and</strong>ard <strong>and</strong> hazardous Class I Division 2 operation.<br />
St<strong>and</strong>ard Portable Model Equipment<br />
Automatic depth adjustment<br />
Line tension adjustment<br />
Integrated AMS Advanced Measurement System<br />
Depth offset adjustment<br />
Ambient temperature correction for counter wheel<br />
Analog line tension display<br />
Analog differential analog line tension display<br />
Digital line tension display<br />
Digital line depth display<br />
Digital line speed display<br />
RS-232 serial port output for corrected depth, line speed,<br />
line tension, units of measurement, <strong>and</strong> time<br />
7-26 Slickline Service Equipment
SmartETD ® System<br />
The <strong>Halliburton</strong> SmartETD® system is an advanced<br />
electronic triggering device that provides an accurate, safe,<br />
<strong>and</strong> reliable method to run <strong>and</strong> fire downhole explosive tools<br />
using slickline. With its built-in sensor <strong>and</strong> memory<br />
capabilities, it can record <strong>and</strong> store downhole temperature<br />
<strong>and</strong> pressure data that can be used by the slickline specialists<br />
to program firing parameters.<br />
The SmartETD tool requires four parameters to be met prior<br />
to firing. These are time, motion, pressure, <strong>and</strong> temperature.<br />
The timing sequence begins when the tool is exposed to<br />
pressure. After the tool stops, any motion resets the<br />
electronic timer. After the SmartETD timer has remained<br />
motionless for a specific period of time <strong>and</strong> has<br />
simultaneously encountered the preset temperature <strong>and</strong><br />
pressure windows, it initiates the firing sequence.<br />
The SmartETD tool will fire the <strong>Halliburton</strong> RED®<br />
rig environment detonator, as well as API RP-67-compliant<br />
devices.<br />
No-Blow, No Drop<br />
Assembly<br />
Top Shock/Centralizer<br />
Quick Lock Assembly<br />
®<br />
SmartETD Tool<br />
HV Shooting Module<br />
Adapter<br />
Selectable Mechanical<br />
Pressure Switch<br />
Shock Absorber<br />
Detonator<br />
Sub/Explosives<br />
as required with<br />
STD 1 3/8-in. GO<br />
Connection<br />
®<br />
VannGun Assembly<br />
Slickline Service Equipment 7-27<br />
HAL15398<br />
SmartETD® System
JobTrak ® Data Job Logger<br />
The JobTrak® data job logger is used with the <strong>Halliburton</strong><br />
advanced measurement system to produce summary logs<br />
that provide a real-time plot of depth, line speed, <strong>and</strong> line<br />
tension. The data logger consists of a portable computer <strong>and</strong><br />
thermal printer packaged in a heavy-duty carrying case. It is<br />
connected to the AMS system through a RS-232 port, <strong>and</strong> the<br />
computer is programmed to convert the AMS data to<br />
graphical form. The data logger can be powered using 12 to<br />
30 volts DC or 110 to 240 volts AC.<br />
HAL8322<br />
JobTrak® Data Job Logger<br />
St<strong>and</strong>ard Mounted Equipment<br />
Temperature rating: -10° to 110°F<br />
Power supply: 12-30 VDC or 110-240 VAC<br />
Maximum line speed: 3,000 ft/min (914 m/min)<br />
Maximum line tension: 5,000 lb (2267 kg)<br />
Plot units per hour settings: 4 in./hr or 8 in./hr<br />
(10 cm/hr or 20 cm/hr)<br />
7-28 Slickline Service Equipment
Memory Production Logging (MPL) Service<br />
<strong>Halliburton</strong>’s memory production logging service provides<br />
solutions to production problems with accurate flow profiles<br />
<strong>and</strong> downhole diagnostics. Logging data is stored in<br />
downhole memory <strong>and</strong> played back on location after the<br />
tools are retrieved from the well. MPL can be used in<br />
producing <strong>and</strong> injecting wells with single- or multi-phase<br />
flow regimes.<br />
Features<br />
Economical in hostile environments – Using slickline<br />
minimizes the risk in CO2 , H2S, or high-pressure<br />
environments. Slickline wellhead pressure control<br />
equipment simplifies rig up <strong>and</strong> operates safely <strong>and</strong><br />
efficiently in dem<strong>and</strong>ing conditions<br />
Proven in horizontal applications – MPL is deployable<br />
on coiled tubing for highly deviated or horizontal wells<br />
Reduced rig space requirements – Small footprint <strong>and</strong><br />
low weight make MPL ideal for small production<br />
platforms <strong>and</strong> mono-pod completions. MPL also<br />
requires less surface equipment <strong>and</strong> crane height than<br />
electric line services<br />
HAL964<br />
This memory production log was obtained for an operator looking to<br />
cut high water production in a formation with a three-phase downhole<br />
flow regime. The MPL service captures logging data on a memory<br />
recorder. The data is equal to data obtained with electric line services.<br />
HAL965<br />
Helicopter portable – MPL can be run with existing<br />
slickline equipment, avoiding the cost of mobilizing a<br />
logging unit<br />
Proven reliability <strong>and</strong> resolution of electric line tools –<br />
MPL string uses the same sensors as the st<strong>and</strong>ard electric<br />
line tools to deliver the same accuracy <strong>and</strong> highresolution<br />
data<br />
Exclusive depth indicators ensure depth accuracy – AMS<br />
advanced slickline depth measurement system or<br />
slickline collar locator provides accurate depth control<br />
for the MPL string, eliminating misruns <strong>and</strong> saving<br />
valuable rig time<br />
Tool strings customized to meet well requirements – All<br />
services can be run with a 1 second sample rate, allowing<br />
approximately 18 hours of logging time. Sample rates as<br />
high as 0.2 seconds can be selected for increased data<br />
density <strong>and</strong> higher resolution<br />
Computing center analysis of the MPL data reveals that the bottom set<br />
of perforations is producing mostly water <strong>and</strong> only 2% of the total oil<br />
production <strong>and</strong> 6% of the gas. Remedial work to plug off the bottom<br />
zone should decrease water production <strong>and</strong> reduce water disposal costs<br />
without greatly affecting hydrocarbon production.<br />
Slickline Service Equipment 7-29
Battery <strong>and</strong><br />
Memory Recorder<br />
Quartz Pressure<br />
Casing Collar<br />
Locator<br />
Gamma Ray<br />
Roller Centralizer<br />
Fluid Density<br />
Differential<br />
Pressure<br />
Capacitance<br />
Water Holdup<br />
Roller Centralizer<br />
Temperature<br />
Caged Fullbore<br />
Spinner<br />
HAL966<br />
Memory Production Logging Service<br />
Tool Description<br />
Battery Housing<br />
Memory Tool<br />
Quartz Pressure<br />
Casing Collar Locator<br />
Gamma Ray<br />
Capacitance Water Holdup<br />
Temperature<br />
Fluid Density Differential Pressure<br />
Caged Fullbore<br />
Continuous<br />
Roller Centralizer<br />
Knuckle Joint<br />
<strong>Services</strong><br />
Spinners<br />
Accessories<br />
Max. Tool OD<br />
in. (mm) Tool Length in. (m)<br />
7-30 Slickline Service Equipment<br />
1.687<br />
(43)<br />
1.68<br />
(43)<br />
1.68<br />
(43)<br />
1.687<br />
(43)<br />
1.687<br />
(43)<br />
1.687<br />
(43)<br />
1.687<br />
(43)<br />
1.687<br />
(43)<br />
1.687<br />
(43)<br />
1.687<br />
(43)<br />
1.687<br />
(43)<br />
1.687<br />
(43)<br />
All tools are rated to 350°F (177°C) <strong>and</strong> 15,000 psi (103 400 kPa)<br />
18<br />
(0.46)<br />
19.5<br />
(0.50)<br />
12.1<br />
(0.31)<br />
18.5<br />
(0.47)<br />
26.6<br />
(0.68)<br />
26.2<br />
(0.67)<br />
11.5<br />
(0.29)<br />
47<br />
(1.19)<br />
34.1<br />
(0.87)<br />
24<br />
(0.61)<br />
23<br />
(0.58)<br />
6.1<br />
(0.15)
LineTrak ® Slickline Inspection Device <strong>and</strong> Wire Management Program<br />
The <strong>Halliburton</strong> LineTrak® slickline<br />
inspection device spots problems that<br />
simply would be impossible for even a<br />
veteran slickline technician to detect.<br />
The device is used to provide<br />
continuous inspection of the entire line<br />
—not just selected areas <strong>and</strong> provides<br />
inspection of both in-service lines as<br />
well as new lines as it is spooled.<br />
Wire Management Program<br />
In addition to periodic inspections for<br />
line abnormalities, a permanent record<br />
of each line’s job history, when utilizing<br />
<strong>Halliburton</strong>’s AMS advanced<br />
measurement system <strong>and</strong> the JobTrak®<br />
data logger, provide a basis for<br />
predicting line failures due to normal<br />
job-related stresses <strong>and</strong> exposure to<br />
hostile well environments.<br />
Wire inspections have become an<br />
integral component of <strong>Halliburton</strong>’s<br />
extensive Wire Management<br />
Program—a program designed to<br />
prevent on-the-job failures.<br />
The LineTrak slickline inspection<br />
device spots problems before they cause<br />
downhole line failure. The following<br />
are examples of problems detected by<br />
the LineTrak device.<br />
This 0.021-in. deep crack (100x magnification)<br />
was detected in a nickel alloy wire with<br />
1,850 cycles.<br />
Damage on left was detected at 462 ft <strong>and</strong> on<br />
right at 368 ft (arrow points to pit on wire) on a<br />
nickel alloy wire.<br />
Abrasion damage on this cobalt alloy wire was<br />
detected before it could cause wire separation.<br />
Slickline Service Equipment 7-31
During inspection, the slickline travels through a coil<br />
matched to its size. A high-frequency, low-power alternating<br />
current running through the coil produces an alternating<br />
magnetic field which generates an electric current, or eddy<br />
current, in the slickline. Any changes or discontinuities in the<br />
slickline’s conductivity affects the eddy current, changing the<br />
coil’s impedance. The inspection device detects the<br />
impedance change.<br />
Pass-fail criteria are based on notched reference wires.<br />
Impedance changes that exceed the established limits identify<br />
line sections that require more detailed inspection or cause a<br />
line to be taken out of service.<br />
Although the LineTrak® inspection device cannot guarantee<br />
you will never have another parted line, it can minimize the<br />
chances of a line failure causing a fishing job in your well.<br />
Wire Management Program Features<br />
Proprietary software developed from extensive empirical<br />
cycle fatigue test data <strong>and</strong> field testing<br />
Utility application in AMS system<br />
Extends wireline life<br />
Minimizes premature line failure<br />
User friendly interface<br />
Tracks wire usage <strong>and</strong> length<br />
Provides graph of used life of line<br />
Discontinuities<br />
7-32 Slickline Service Equipment<br />
Coil<br />
AC<br />
Generator/Indicator<br />
Magnetic<br />
Field<br />
Slickline<br />
Direction<br />
of Movement<br />
Inspection System Using Self-Comparison Differential Coils<br />
Wire Management Program
Deepwater Riserless Subsea Light Well<br />
Intervention System<br />
The <strong>Halliburton</strong> deepwater riserless subsea light well<br />
intervention system offers complete well intervention<br />
solutions.<br />
Features<br />
Reduced well intervention costs on subsea wells<br />
No workover riser during operation<br />
Deepwater Riserless Intervention System<br />
System can be operated from a more cost-effective<br />
intervention DP vessel<br />
Ideal intervention method on deepwater wells<br />
Increases subsea well availability<br />
Reduced chance of damage resident pipelines <strong>and</strong><br />
structures<br />
Slickline Service Equipment 7-33
7-34 Slickline Service Equipment
Mobilization<br />
LOGIQ Logging Truck<br />
LOGIQ logging trucks are an evolution in onshore logging<br />
technology. The trucks are designed to operate all of the new<br />
evolution tools at well depths of up to 27,000 ft in single<br />
drum (open-hole) or dual drum (open <strong>and</strong> cased-hole)<br />
configuration. The latest state-of-the-art technology <strong>and</strong><br />
engineering design make the truck <strong>and</strong> computer system a<br />
platform that can be upgraded as technology evolves.<br />
Logging Cabin Features<br />
Exterior<br />
– Material – 1/8-in. aluminum<br />
– Construction – welded aluminum<br />
– Insulation – 2-in. urethane foam<br />
– Entrance(s) – single door<br />
Interior<br />
– Material – brushed anodized aluminum skin<br />
– Console – winch operator console for depth<br />
panel, engine, <strong>and</strong> generator panel<br />
– Window – one large sliding window facing reel<br />
<strong>and</strong> frame assembly<br />
LOGIQ Logging Truck<br />
Truck Chassis <strong>and</strong> Engine Specifications<br />
Power Distribution Panel<br />
– Power type – 110V <strong>and</strong> 220V sockets<br />
– Direct Lights – 110V <strong>and</strong> 12V direct lights<br />
– Floodlights – 110V, 500W quartz<br />
– Air Conditioners – four DuoTherm; 13,500 BTU/<br />
5,600 BTU heating for each<br />
– Intercom – 3M Model D-15<br />
Curbside Tool Racks (with airbags)<br />
– Top – four, 2-in. diameter tools, maximum length<br />
92 in. (233.7 cm)<br />
– Middle, Lower – holds two, 4-in. diameter tools,<br />
maximum length 98 in. (249 cm)<br />
Roadside Tool Racks (with airbags)<br />
– Top – four, 2-in. diameter tools, maximum length<br />
88 in. (223.5 cm)<br />
– Middle, Lower – holds two, 4-in. diameter tools,<br />
maximum length 136 in. (345.4 cm)<br />
Underbelly Tool Rack<br />
– Holds four, 5-in. diameter tools <strong>and</strong> two, 4-in.<br />
diameter tools; maximum length 22 ft (6.7 m)<br />
with pneumatic tool retainers<br />
Make/Model Height Width Length Wheel Base Cab to Axle Engine Model Horsepower Fuel Tanks<br />
Kenworth<br />
T-800 6X4<br />
13 ft, 2 in.<br />
(4.01 m)<br />
7 ft, 11 in.<br />
(2.41 m)<br />
38 ft, 4 in.<br />
(11.68 m)<br />
24 ft, 6 in.<br />
(8.86 m)<br />
16 ft<br />
(4.87 m)<br />
Caterpillar<br />
Cat-13<br />
380 hp at<br />
2100 RPM<br />
Two 24.5-in.<br />
diameter aluminum,<br />
cap: 110 <strong>and</strong> 50 USG<br />
Mobilization 8-1<br />
Mobilization
Winch Specifications<br />
Two-speed transmission, speeds from 55,000 ft/hour<br />
down to 360 ft/hour with an enhanced low speed option<br />
down to 50 ft per hour.<br />
Single speed transmission cased-hole drum with speeds<br />
up to 52,000 ft/hour <strong>and</strong> down to 360 ft/hour with an<br />
enhanced slow speed option down to 50 ft/hour<br />
Rexroth AA4VG pumps <strong>and</strong> AA6V motors with<br />
electronic controls<br />
Large drum capable of holding 25,500 of 0.490-in.<br />
heptacable slammer cable or 28,500 ft of 0.472-in.<br />
heptacable slammer. Small drum capable of holding<br />
22,500 ft of 5/16 single conductor cable or 28,500 ft of<br />
7/32 single conductor cable.<br />
Satellite dish <strong>and</strong> communications optional<br />
8-2 Mobilization
LOGIQ Modular Skid Unit<br />
The LOGIQ DNV 2.7.1 certified logging skids are an<br />
evolution in offshore logging technology. The three-piece<br />
modular skids are designed to operate the most complex<br />
logging jobs in the harshest offshore <strong>and</strong> l<strong>and</strong> environments.<br />
The three-module design allows for the three modules to<br />
operate together or separate changing the footprint of the<br />
skid to better match the space available.<br />
LOGIQ Modular Skid Unit<br />
Setup times are greatly reduced because of the slewing<br />
mechanism of the winch module <strong>and</strong> service multiple wells<br />
as well. It will run all of the new evolution tools at well depths<br />
of up to 27,000 ft, in single drum (open-hole) or dual drum<br />
(open <strong>and</strong> cased-hole) configuration. The latest state-of-theart<br />
technology <strong>and</strong> engineering design make the skid <strong>and</strong><br />
computer system a platform that can be upgraded as<br />
technology evolves.<br />
Mobilization 8-3
Cabin Module<br />
The cabin module unit can be transported as a single DNV<br />
2.7.1 certified lift. The unit has entry doors on both sides,<br />
<strong>and</strong> cooling <strong>and</strong> heating is provided by four units. The<br />
exterior material is 3/16-in. aluminum with 2.0-in. urethane<br />
foam walls. The cabin is ergonomically designed <strong>and</strong> holds a<br />
single or double LOGIQ logging system. The control panel<br />
includes all functions, such as: gauges for power pack, winch<br />
controls, generator controls, start/stop, pump controls, <strong>and</strong><br />
an integrated touch screen depth panel.<br />
Length<br />
in. (m)<br />
136<br />
(3.45)<br />
Cabin Module Specifications<br />
Height<br />
in. (m)<br />
113<br />
(2.87)<br />
Width<br />
in. (m)<br />
96<br />
(2.44)<br />
Cabin Module<br />
Weight<br />
lb (kg)<br />
11,350<br />
(5148)<br />
8-4 Mobilization
Winch Module<br />
The winch module unit can be transported as a single DNV<br />
2.7.1 certified lift. It has interchangeable reels for open-hole<br />
<strong>and</strong> cased-hole purposes. Both have maximum slew rate<br />
angles of up to ± 12°. The open-hole reel has a two-speed<br />
direct drive transmission. Speeds vary from 55,000 ft/hour<br />
down to 360 ft/hour with an enhanced low speed option<br />
down to 50 ft/hour.<br />
The cased-hole reel has a single speed direct drive<br />
transmission with speeds up to 52,000 ft/hour <strong>and</strong> down to<br />
360 ft/hour with an enhanced slow speed option down to<br />
50 ft/hour.<br />
It also features a Rexroth 90 cc pump <strong>and</strong> 80 cc motors with<br />
electronic controls.<br />
The unit includes a large drum capable of holding 25,500 ft<br />
of 0.490-in. heptacable slammer cable or 28,500 ft of<br />
0.472-in. heptacable slammer. The small drum is capable of<br />
holding 22,500 ft of 5/16 single conductor cable or 28,500 ft<br />
of 7/32 single conductor cable.<br />
Satellite dish <strong>and</strong> communications optional<br />
Length<br />
in. (m)<br />
72<br />
(1.83)<br />
Height<br />
in. (m)<br />
113<br />
(2.87)<br />
Winch Module Specifications<br />
Width<br />
in. (m)<br />
96<br />
(2.44)<br />
Winch Module<br />
Weight<br />
lb (kg) Certification<br />
25,200<br />
(11 455)<br />
DNV 2.7.1 /<br />
EN12079 certified<br />
Mobilization 8-5
Power Pack<br />
The power pack unit can be transported as a single DNV<br />
2.7.1 certified lift. Its main component is the Caterpillar 3126<br />
EURO-3 engine with 230 hp. It runs the hydraulic pumps for<br />
the winch <strong>and</strong> 30 kW hydraulic generator <strong>and</strong> other auxiliary<br />
hydraulic controls. All electrical <strong>and</strong> hydraulic connections<br />
are quick change so set up time is minimal. All service access<br />
points are easy to reach. The power pack unit has an enclosed<br />
pollution drip pan with easy access drain plugs. It also<br />
includes air-start with st<strong>and</strong>ard rig air connections.<br />
Length<br />
in. (m)<br />
60<br />
(1.52)<br />
Power Pack Module Specifications<br />
Height<br />
in. (m)<br />
113<br />
(2.87)<br />
Width<br />
in. (m)<br />
Power Pack Module<br />
Weight<br />
lb (kg)<br />
8-6 Mobilization<br />
96<br />
(2.44)<br />
7,150<br />
(3250)
Mnemonics<br />
Mnemonic: Refers to the Curve Mnemonic - LIS / DLIS<br />
Unit: Refers to the Engineering Units—LIS Eng / Metric; DLIS Eng / Metric<br />
Tool: Refers to the logging tool for the curve.<br />
Description:<br />
Described the recorded Curve<br />
Serv_Name: Refers to the General Service (combined tools)<br />
Refers to the Data format classification <strong>and</strong> processing status<br />
Type_Data:<br />
RES = Result curve<br />
INP = Processed Input data<br />
TEL = Telemetry with some processing applied<br />
This is a generalized listing of current supported tools <strong>and</strong> is not intended to include older tools,<br />
software versions or data systems. Dual detector tools may utilize either N or 1 to distinguish<br />
Near detector <strong>and</strong> F or 2 to distinguish Far detector.<br />
Mnemonics 9-1<br />
Mnemonics
<strong>Wireline</strong> <strong>and</strong> <strong>Perforating</strong> <strong>Services</strong> Mnemonics<br />
Serv_Name<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
ACRT - ARRAY COMP TRUE RES HRM2 RT RESISTIVITY MAP - TWO FOOT HRM2 RES<br />
ACRT - ARRAY COMP TRUE RES RMAN RIGHT MANDREL RMAN RES<br />
ACRT - ARRAY COMP TRUE RES RF90 OHMM OHMM 90 IN RADIAL RESISTIVITY 4FT RF90 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RF60 OHMM OHMM 60 IN RADIAL RESISTIVITY 4FT RF60 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RF30 OHMM OHMM 30 IN RADIAL RESISTIVITY 4FT RF30 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RF20 OHMM OHMM 20 IN RADIAL RESISTIVITY 4FT RF20 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RF10 OHMM OHMM 10 IN RADIAL RESISTIVITY 4FT RF10 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RF06 OHMM OHMM 6 IN RADIAL RESISTIVITY 4 FT RF06 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES LSO LEFT STANDOFF LSO RES<br />
ACRT - ARRAY COMP TRUE RES LMAN LEFT MANDREL LMAN RES<br />
ACRT - ARRAY COMP TRUE RES CO60 MMHO MMHO 60 IN RADIAL CONDUCTIVITY 1FT CO60 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES HRM4 RT RESISTIVITY MAP - FOUR FOOT HRM4 RES<br />
ACRT - ARRAY COMP TRUE RES RO20 OHMM OHMM 20 IN RADIAL RESISTIVITY 1 FT RO20 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES HRM1 RT RESISTIVITY MAP - ONE FOOT HRM1 RES<br />
ACRT - ARRAY COMP TRUE RES ECC ECCENTRICITY ECC RES<br />
ACRT - ARRAY COMP TRUE RES D2 IN IN OUTER RADIAL DEPTH OF INVASION D2 in IN RES<br />
ACRT - ARRAY COMP TRUE RES D1 IN MM INNER RADIAL DEPTH OF INVASION D1 in mm RES<br />
ACRT - ARRAY COMP TRUE RES DI IN MM RADIAL DEPTH OF INVASION DI in mm RES<br />
ACRT - ARRAY COMP TRUE RES CT90 MMHO MMHO 90 IN RADIAL CONDUCTIVITY 2FT CT90 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CT06 MMHO MMHO 6 IN RADIAL CONDUCTIVITY 2FT CT06 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CT20 MMHO MMHO 20 IN RADIAL CONDUCTIVITY 2FT CT20 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CT10 MMHO MMHO 10 IN RADIAL CONDUCTIVITY 2FT CT10 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CO90 MMHO MMHO 90 IN RADIAL CONDUCTIVITY 1FT CO90 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES INCL INCLINATION INCL RES<br />
ACRT - ARRAY COMP TRUE RES RT60 OHMM OHMM 60 IN RADIAL RESISTIVITY 2 FT RT60 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES TMPF TEMPERATURE FEEDPIPE - CALC TMPF RES<br />
ACRT - ARRAY COMP TRUE RES SED6 MMHO MMHO SKIN EFFECT CORRECTIONS D6 SED6 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES SEU5 MMHO MMHO SKIN EFFECT CORRECTIONS U5 SEU5 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES SED4 MMHO MMHO SKIN EFFECT CORRECTIONS D4 SED4 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES SED3 MMHO MMHO SKIN EFFECT CORRECTIONS D3 SED3 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES SED2 MMHO MMHO SKIN EFFECT CORRECTIONS D2 SED2 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES SED1 MMHO MMHO SKIN EFFECT CORRECTIONS D1 SED1 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES SMUD OHMM OHMM MUD RESISTIVITY - CALCULATED SMUD ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RMUD OHMM OHMM MUD RESISTIVITY RMUD ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RXO/RT OHMM OHMM UNIVADED ZONE RESISTIVITY RXO/RT ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RO06 OHMM OHMM 6 IN RADIAL RESISTIVITY 1 FT RO06 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RT90 OHMM OHMM 90 IN RADIAL RESISTIVITY 2 FT RT90 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RO10 OHMM OHMM 10 IN RADIAL RESISTIVITY 1 FT RO10 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RT30 OHMM OHMM 30 IN RADIAL RESISTIVITY 2 FT RT30 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RT20 OHMM OHMM 20 IN RADIAL RESISTIVITY 2 FT RT20 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RT10 OHMM OHMM 10 IN RADIAL RESISTIVITY 2 FT RT10 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RT06 OHMM OHMM 6 IN RADIAL RESISTIVITY 2 FT RT06 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RT OHMM OHMM TRUE RESISTIVITY UNIVADED ZONE RT ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RSO RIGHT STANDOFF RSO RES<br />
9-2 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
ACRT - ARRAY COMP TRUE RES RO90 OHMM OHMM 90 IN RADIAL RESISTIVITY 1 FT RO90 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RO60 OHMM OHMM 60 IN RADIAL RESISTIVITY 1 FT RO60 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES RO30 OHMM OHMM 30 IN RADIAL RESISTIVITY 1 FT RO30 ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES CT30 MMHO MMHO 30 IN RADIAL CONDUCTIVITY 2FT CT30 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES RXO OHMM OHMM UNIVADED ZONE RESISTIVITY RXO ohm.m ohm.m RES<br />
ACRT - ARRAY COMP TRUE RES BCD4 MMHO MMHO BOREHOLE CORRECTIONS D4 BCD4 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CT60 MMHO MMHO 60 IN RADIAL CONDUCTIVITY 2FT CT60 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CO06 MMHO MMHO 6 IN RADIAL CONDUCTIVITY 1FT CO06 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES BCD1 MMHO MMHO BOREHOLE CORRECTIONS D1 BCD1 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES BCD3 MMHO MMHO BOREHOLE CORRECTIONS D3 BCD3 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES BCD6 MMHO MMHO BOREHOLE CORRECTIONS D6 BCD6 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES BCD5 MMHO MMHO BOREHOLE CORRECTIONS D5 BCD5 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CALU IN IN CAL DIAMETER USED CALU in IN RES<br />
ACRT - ARRAY COMP TRUE RES CDIA IN IN CALCULATED DIAMETER CDIA in IN RES<br />
ACRT - ARRAY COMP TRUE RES CF10 MMHO MMHO 10 IN RADIAL CONDUCTIVITY 4FT CF10 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CF20 MMHO MMHO 20 IN RADIAL CONDUCTIVITY 4FT CF20 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CO10 MMHO MMHO 10 IN RADIAL CONDUCTIVITY 1FT CO10 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CF06 MMHO MMHO 6 IN RADIAL CONDUCTIVITY 4FT CF06 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CF60 MMHO MMHO 60 IN RADIAL CONDUCTIVITY 4FT CF60 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CF90 MMHO MMHO 90 IN RADIAL CONDUCTIVITY 4FT CF90 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES BCD2 MMHO MMHO BOREHOLE CORRECTIONS D2 BCD2 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES ACCZ ACCELEROMETER Z ACCZ RES<br />
ACRT - ARRAY COMP TRUE RES CO20 MMHO MMHO 20 IN RADIAL CONDUCTIVITY 1FT CO20 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CF30 MMHO MMHO 30 IN RADIAL CONDUCTIVITY 4FT CF30 0.001/ohm 0.001/ohm RES<br />
ACRT - ARRAY COMP TRUE RES CO30 MMHO MMHO 30 IN RADIAL CONDUCTIVITY 1FT CO30 0.001/ohm 0.001/ohm RES<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
TT22 TT_T2R2 TT22 INP<br />
ALPH ALPHA ALPHA INP<br />
TT2 US US FAR TRAVEL TIME TT2 uS uS RES<br />
DT2 US/F US/M DELTA - TIME TRANSMITTER 2 DT2 uS/ft US/M RES<br />
TT12 UPPER XMTR TRAVEL TIME TT_T1R2 TT12 INP<br />
TT11 UPPER XMTR TRAVEL TIME TT_T1R1 TT11 INP<br />
TT21 TT_T2R1 TT21 INP<br />
AMPL DB DB AMPLITUDE AMPL dB dB RES<br />
AMP MV MV CBL - PIPE AMPLITUDE AMP mv mv RES<br />
DT1 US/F US/M DELTA - TIME TRANSMITTER 1 DT1 uS/ft US/M RES<br />
FRMC TOOL FRAME COUNT FRMC RES<br />
TT US/F US/M CBL - PIPE TRAVEL TIME TT uS/ft US/M RES<br />
TT1 US US NEAR TRAVEL TIME TT1 uS uS RES<br />
WFFW WAVEFORM - ALL WFFW INP<br />
ITTT INTEGRATED TRAVEL TIME TOTAL ITTT RES<br />
WMSG WAVEFORM - MSG WMSG INP<br />
Mnemonics 9-3<br />
Type_<br />
Data
Serv_Name<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
BCDT/BSAT/BCS/CBL - BH<br />
COMP ARRAY SONIC<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
BI CBL - BOND INDEX BI RES<br />
ITT INTEGRATED TRAVEL TIME MARK ITT RES<br />
DT US/F US/M DELTA TIME COMPRESSIVE DT uS/ft US/M RES<br />
DTRC DELTA T AT RECEIVER DT_RCV INP<br />
DTUN DELTA T UNFILTERED DT_UNF INP<br />
DTXM DELTA T AT TRANSMITTER DT_XMT INP<br />
ERR ERROR ERROR INP<br />
FNOI FAR RECEIVER NOISE FNOISE INP<br />
GFAR FAR RECEIVER GAIN GAIN_F INP<br />
MSGR MSG RECEIVER MSGRCV INP<br />
GNEA NEAR RECEIVER GAIN GAIN_N INP<br />
SPHI DECP DECP SONIC POROSITY SPHI 100 pu 100 pu RES<br />
MSGG MSG GAIN MSGGAI INP<br />
NNOI NEAR RECEIVER NOISE NNOISE INP<br />
PKCD PICK CODE PKCODE INP<br />
QDT DELTA TIME QUALITY QDT RES<br />
SDT2 US/F US/M DELTA T (2 FOOT) SDT2 uS/ft US/M RES<br />
BHPT - BORE HOLE PROP TOOL FLWT LBS/G K/M3 FLUID WEIGHT FLWT LBS/G Kg/m3 RES<br />
BHPT - BORE HOLE PROP TOOL DTEM DEGF DEGC DIFFERENTIAL TEMPERATURE DTEM degF degC RES<br />
BHPT - BORE HOLE PROP TOOL DPRS PSIA KPA DIFFERENTIAL PRESSURE DPRS PSIA Kpa RES<br />
BHPT - BORE HOLE PROP TOOL PRES PSIA KPA BOREHOLE PRESSURE BHPRES PSIA Kpa RES<br />
BHPT - BORE HOLE PROP TOOL PXIT DEGF DEGC PRESSURE XDCR INTERNAL TEMP PXIT degF degC RES<br />
BHPT - BORE HOLE PROP TOOL PTMP DEGF DEGC PROBE INTERNAL TEMP PTMP degF degC RES<br />
BHPT - BORE HOLE PROP TOOL RES OHM-M OHM-M BOREHOLE RESISTIVITY BHRES OHM-M OHM-M RES<br />
BHPT - BORE HOLE PROP TOOL TEMP DEGF DEGC BOREHOLE TEMPERATURE BHTEMP degF degC RES<br />
CALIPER - 2 ARM AHVT FT3 M3 ANNULAR VOLUME TOTAL AHVT ft3 m3 RES<br />
CALIPER - 2 ARM BHV FT3 M3 BORE HOLE VOLUME MARK BHV ft3 m3 RES<br />
CALIPER - 2 ARM BHVT FT3 M3 BOREHOLE VOLUME TOTAL BHVT ft3 m3 RES<br />
CALIPER - 2 ARM CALI IN MM CALIPER CALI in mm RES<br />
CALIPER - 2 ARM DCAL IN MM DIFFERENTIAL CALIPER DCAL in mm RES<br />
CALIPER - 2 ARM AHV FT3 M3 ANNULAR VOLUME MARK AHV ft3 m3 RES<br />
CAST-V - CIRCUM ACOU SCAN AM32 IN MM CALIPER 32 AM32 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM31 IN MM CALIPER 31 AM31 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM30 IN MM CALIPER 30 AM30 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM29 IN MM CALIPER 29 AM29 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM28 IN MM CALIPER 28 AM28 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM27 IN MM CALIPER 27 AM27 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM33 IN MM CALIPER 33 AM33 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM25 IN MM CALIPER 25 AM25 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM38 IN MM CALIPER 38 AM38 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM26 IN MM CALIPER 26 AM26 in mm RES<br />
9-4 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
CAST-V - CIRCUM ACOU SCAN AM34 IN MM CALIPER 34 AM34 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM35 IN MM CALIPER 35 AM35 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM24 IN MM CALIPER 24 AM24 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM37 IN MM CALIPER 37 AM37 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM20 IN MM CALIPER 20 AM20 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM39 IN MM CALIPER 39 AM39 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM40 IN MM CALIPER 40 AM40 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AMMN CAST AMPLITUDE - MINIMUM AMMN RES<br />
CAST-V - CIRCUM ACOU SCAN AMMX CAST AMPLITUDE - MAXIMUM AMMX RES<br />
CAST-V - CIRCUM ACOU SCAN AMP CAST AMPLITUDE SCAN AMP RES<br />
CAST-V - CIRCUM ACOU SCAN AVAM AVERAGE AMPLITUDE AVAM INP<br />
CAST-V - CIRCUM ACOU SCAN AM36 IN MM CALIPER 36 AM36 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM12 IN MM CALIPER 12 AM12 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM01 IN MM CALIPER 01 AM01 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM02 IN MM CALIPER 02 AM02 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM03 IN MM CALIPER 03 AM03 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM04 IN MM CALIPER 04 AM04 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM05 IN MM CALIPER 05 AM05 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM06 IN MM CALIPER 06 AM06 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM07 IN MM CALIPER 07 AM07 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM08 IN MM CALIPER 08 AM08 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM09 IN MM CALIPER 09 AM09 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM22 IN MM CALIPER 22 AM22 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM11 IN MM CALIPER 11 AM11 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM23 IN MM CALIPER 23 AM23 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM13 IN MM CALIPER 13 AM13 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM14 IN MM CALIPER 14 AM14 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM15 IN MM CALIPER 15 AM15 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM16 IN MM CALIPER 16 AM16 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM17 IN MM CALIPER 17 AM17 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM18 IN MM CALIPER 18 AM18 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM19 IN MM CALIPER 19 AM19 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AVOD AVERAGE CASING OD AVOD RES<br />
CAST-V - CIRCUM ACOU SCAN AM21 IN MM CALIPER 21 AM21 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AM10 IN MM CALIPER 10 AM10 in mm RES<br />
CAST-V - CIRCUM ACOU SCAN THKP THICKNESS PLOT THKP RES<br />
CAST-V - CIRCUM ACOU SCAN MXID IN MM MAXIMUM INSIDE DIAMETER MXID in mm RES<br />
CAST-V - CIRCUM ACOU SCAN MXIR IN MM MAXIMUM INSIDE RADIUS MXIR in mm RES<br />
CAST-V - CIRCUM ACOU SCAN MXTK IN MM MAXIMUM THICKNESS MXTK in mm RES<br />
CAST-V - CIRCUM ACOU SCAN MXZ MAXIMUM IMPEDENCE MXZ RES<br />
CAST-V - CIRCUM ACOU SCAN NBS NUMBER OF MISSED SHOTS NBS RES<br />
CAST-V - CIRCUM ACOU SCAN OVAL OVALITY OVAL RES<br />
CAST-V - CIRCUM ACOU SCAN PAMP PEAK AMPLITUDE PAMP RES<br />
CAST-V - CIRCUM ACOU SCAN RADI IN MM CAST RADIUS SCAN RADI in mm RES<br />
CAST-V - CIRCUM ACOU SCAN RAMN IN MM CAST MINIMUM RADIUS RAMN in mm RES<br />
CAST-V - CIRCUM ACOU SCAN RAMX INCH INCH CAST MAXIMUM RADIUS RAMX in INCH RES<br />
CAST-V - CIRCUM ACOU SCAN AVID IN MM AVERAGE INSIDE DIAMETER AVID in mm RES<br />
CAST-V - CIRCUM ACOU SCAN THET DIRECTION FROM HIGH SIDE THETA RES<br />
CAST-V - CIRCUM ACOU SCAN MNTK IN MM MINIMUM THICKNESS MNTK in mm RES<br />
Mnemonics 9-5<br />
Type_<br />
Data
Serv_Name<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
CAST-V - CIRCUM ACOU SCAN TT .1 ms .1ms CAST TRANSIT TIME TT .1 ms .1ms RES<br />
CAST-V - CIRCUM ACOU SCAN VOL1 IMPEDENCE VOLUME 1 VOL1 RES<br />
CAST-V - CIRCUM ACOU SCAN VOL2 IMPEDENCE VOLUME 2 VOL2 RES<br />
CAST-V - CIRCUM ACOU SCAN VOL3 IMPEDENCE VOLUME 3 VOL3 RES<br />
CAST-V - CIRCUM ACOU SCAN VOL4 IMPEDENCE VOLUME 4 VOL4 RES<br />
CAST-V - CIRCUM ACOU SCAN VOL5 IMPEDENCE VOLUME 5 VOL5 RES<br />
CAST-V - CIRCUM ACOU SCAN XO X COORDINATE FROM CENTER XO RES<br />
CAST-V - CIRCUM ACOU SCAN YO Y COORDINATE FROM CENTER YO RES<br />
CAST-V - CIRCUM ACOU SCAN ZMUD IMPEDENCE OF BOREHOLE FLUID ZMUD RES<br />
CAST-V - CIRCUM ACOU SCAN ZP IMPEDENCE PLOT ZP RES<br />
CAST-V - CIRCUM ACOU SCAN SEQ SCAN SEQUENCE SEQ TEL<br />
CAST-V - CIRCUM ACOU SCAN GAS GAS FLAG GAS RES<br />
CAST-V - CIRCUM ACOU SCAN AVIR IN MM AVERAGE INSIDE RADIUS AVIR in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AVTK IN MM AVERAGE THICKNESS AVTK in mm RES<br />
CAST-V - CIRCUM ACOU SCAN AVZ AVERAGE IMPEDENCE AVZ RES<br />
CAST-V - CIRCUM ACOU SCAN BSI BAD SHOT INDEX BSI RES<br />
CAST-V - CIRCUM ACOU SCAN DIAV IN MM CAST AVERAGE DIAMETER DIAV in mm RES<br />
CAST-V - CIRCUM ACOU SCAN DIMN IN MM CAST MINIMUM DIAMETER DIMN in mm RES<br />
CAST-V - CIRCUM ACOU SCAN DIMX IN MM CAST MAXIMUM DIAMETER DIMX in mm RES<br />
CAST-V - CIRCUM ACOU SCAN DVTH DEVIATION OF THICKNESS DVTK RES<br />
CAST-V - CIRCUM ACOU SCAN DVZ DEVIATION OF IMPEDENCE DVZ RES<br />
CAST-V - CIRCUM ACOU SCAN ECTY ECCENTRICITY ECTY RES<br />
CAST-V - CIRCUM ACOU SCAN MSPD REV XDUCER REVOLUTIONS / SEC MSPD REV INP<br />
CAST-V - CIRCUM ACOU SCAN FTT US/FT US/M FLUID TRAVEL TIME FTT uS/ft US/M RES<br />
CAST-V - CIRCUM ACOU SCAN MNZ MINIMUM IMPEDENCE MNZ RES<br />
CAST-V - CIRCUM ACOU SCAN HIGD IN MM HIGH SCALE FOR DISTANCE HIGHD in mm RES<br />
CAST-V - CIRCUM ACOU SCAN HIGT IN MM HIGH SCALE FOR THICKNESS HIGHT in mm RES<br />
CAST-V - CIRCUM ACOU SCAN HRAD IN MM HOLE RADIUS HRAD in mm RES<br />
CAST-V - CIRCUM ACOU SCAN IDP INNER DIAMETER PLOT IDP RES<br />
CAST-V - CIRCUM ACOU SCAN IRP INNER RADIUS PLOT IRP RES<br />
CAST-V - CIRCUM ACOU SCAN LOWD IN MM LOW SCALE FOR DISTANCE LOWD in mm RES<br />
CAST-V - CIRCUM ACOU SCAN LOWT IN MM LOW SCALE FOR THICKNESS LOWT in mm RES<br />
CAST-V - CIRCUM ACOU SCAN MDWT GMCC MUD WEIGHT GM/CC MUDWT GMCC RES<br />
CAST-V - CIRCUM ACOU SCAN MNID IN MM MINIMUM INSIDE DIAMETER MNID in mm RES<br />
CAST-V - CIRCUM ACOU SCAN MNIR IN MM MINIMUM INSIDE RADIUS MNIR in mm RES<br />
CAST-V - CIRCUM ACOU SCAN MCNS MUDCELL WAVE NUMB SAMPLES MCNS RES<br />
CAST-V - CIRCUM ACOU SCAN FREQ KHZ KHZ MEASURED KHZ FREQ 1000 Hz 1000 Hz RES<br />
CAST-V - CIRCUM ACOU SCAN LWAV LONG WAVEFORM LWAV RES<br />
CAST-V - CIRCUM ACOU SCAN MZP CALCULTED MUD IMPEDANCE MZP RES<br />
CAST-V - CIRCUM ACOU SCAN MNCS MINIMUM COMPRESSIVE STRENGTH MNCS RES<br />
CAST-V - CIRCUM ACOU SCAN MFTT MUDCELL FTT REFLECTION MFTT RES<br />
CAST-V - CIRCUM ACOU SCAN MDN MUDCELL DENSITY MDN RES<br />
CAST-V - CIRCUM ACOU SCAN MCSQ MUDCELL SEQUENCE NUMBER MCSQ RES<br />
CAST-V - CIRCUM ACOU SCAN AVCS AVERAGE COMPRESSIVE STRENGTH AVCS RES<br />
CAST-V - CIRCUM ACOU SCAN CSP COMPRESSIVE STRENGTH IMAGE CSP RES<br />
CAST-V - CIRCUM ACOU SCAN AVRA AVERAGE RADIUS AVRA INP<br />
CAST-V - CIRCUM ACOU SCAN LSTO START TIME LONG WAVEFORM LSTO RES<br />
CAST-V - CIRCUM ACOU SCAN RB RELATIVE BEARING RB RES<br />
CAST-V - CIRCUM ACOU SCAN LWNS LONG WAVEFORM NUMB. SAMPLES LWNS RES<br />
9-6 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
CAST-V - CIRCUM ACOU SCAN LWSQ LONG WAVEFORM SEQUENCE NUMBER LWSQ RES<br />
CAST-V - CIRCUM ACOU SCAN LWNS LONG WAVEFORM NUMB. SAMPLES LWNS RES<br />
CAST-V - CIRCUM ACOU SCAN MAMP MUDCELL PEAK AMPLITUDE MAMP RES<br />
CAST-V - CIRCUM ACOU SCAN MATN CALCULATED MUD ATTENUATION MATN RES<br />
CAST-V - CIRCUM ACOU SCAN MCAL CALIBRATED MUDCELL OFFSET MCAL RES<br />
CAST-V - CIRCUM ACOU SCAN MCF CALCULATED MUDCELL FREQUENCY MCF RES<br />
CAST-V - CIRCUM ACOU SCAN FSRA FIRST SHOT RAW AMPLITUDE FSRA RES<br />
CAST-V - CIRCUM ACOU SCAN RWAV FAST CAST TRANSDUCER WAVEFORM RWAV RES<br />
CAST-V - CIRCUM ACOU SCAN SMRT SAMPLE RATE SMRT RES<br />
CAST-V - CIRCUM ACOU SCAN RBRF TOOL REFERENCE ANGLE RBRF RES<br />
CAST-V - CIRCUM ACOU SCAN MNZD MINIMUM DIFFERENTIAL IMPEDANCE MNZD RES<br />
CCL - CASING COLLAR<br />
LOCATOR<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
CCL CASING COLLAR LOCATOR CCL RES<br />
CSNG - COMP SPECT GAMMA HBAR BARITE CORR FACTOR - RUN AVG HBAR RES<br />
CSNG - COMP SPECT GAMMA MINU URANIUM - MIN ERROR MINU RES<br />
CSNG - COMP SPECT GAMMA MINT THORIUM - MIN ERROR MINT RES<br />
CSNG - COMP SPECT GAMMA MINK POTASSIUM - MIN ERROR MINK RES<br />
CSNG - COMP SPECT GAMMA MAXU URANIUM - MAX ERROR MAXU RES<br />
CSNG - COMP SPECT GAMMA MAXT THORIUM - MAX ERROR MAXT RES<br />
CSNG - COMP SPECT GAMMA MAXK POTASSIUM - MAX ERROR MAXK RES<br />
CSNG - COMP SPECT GAMMA LSPC LOW ENERGY SPECTRUM LSPC RES<br />
CSNG - COMP SPECT GAMMA HBHK BORHOLE POTASSIUM - RUN AVG HBHK RES<br />
CSNG - COMP SPECT GAMMA ERTO ERROR GAMMA RAY TOTAL ERTO RES<br />
CSNG - COMP SPECT GAMMA ERTC ERROR GAMMA RAY KT ERTC RES<br />
CSNG - COMP SPECT GAMMA EHBK BOREHOLE K CONCENTRATION ERROR EHBK RES<br />
CSNG - COMP SPECT GAMMA CVBF COMPUTED BARITE FACTOR CVBF RES<br />
CSNG - COMP SPECT GAMMA CRDF RESOLUTION DEGRADE FACTOR CRDF RES<br />
CSNG - COMP SPECT GAMMA CGCF SPECTRAL GAIN CORR FACTOR CGCF RES<br />
CSNG - COMP SPECT GAMMA CASR CSNG CASING RATIO CASR RES<br />
CSNG - COMP SPECT GAMMA HSPC HIGH ENERGY SPECTRUM HSPC RES<br />
CSNG - COMP SPECT GAMMA STAB CSNG STABILIZER STAB INP<br />
CSNG - COMP SPECT GAMMA LITR LITHOLOGY RATIO LITR RES<br />
CSNG - COMP SPECT GAMMA LSPD LINE SPEED LSPEED INP<br />
CSNG - COMP SPECT GAMMA NAVG TPU INTERVALS PER DEPTH INTERv NUMAVG RES<br />
CSNG - COMP SPECT GAMMA NOIS CPS CPS SPECTRAL NOISE NOIS 1.0/S 1.0/S RES<br />
CSNG - COMP SPECT GAMMA POTA % % POTASSIUM POTA % % RES<br />
CSNG - COMP SPECT GAMMA SPEH CSNG HIGH ENERGY SPECTRUM SUM SPEH INP<br />
CSNG - COMP SPECT GAMMA SPEL CSNG LOW ENERGY SPECTRUM SUM SPEL INP<br />
CSNG - COMP SPECT GAMMA AMER AMERICIUM COUNTS AMER INP<br />
CSNG - COMP SPECT GAMMA SRCF SOURCE FACTOR SRCF RES<br />
CSNG - COMP SPECT GAMMA GRTH GAPI GAPI GAMMA THORIUM GRTH gAPI gAPI RES<br />
CSNG - COMP SPECT GAMMA SWPO SWITCH POSITION SW_POS INP<br />
CSNG - COMP SPECT GAMMA THOR PPM PPM THORIUM THOR ppm ppm RES<br />
CSNG - COMP SPECT GAMMA TKRT CSNG RATIO THORIUM POTASSIUM TKRT RES<br />
CSNG - COMP SPECT GAMMA TOID CSNG TOOL ID TOOLID INP<br />
CSNG - COMP SPECT GAMMA TOTF CSNG TOTAL SPECTRA COUNTER TOTFRM INP<br />
CSNG - COMP SPECT GAMMA TURT CSNG RATIO THORIUM URANIUM TURT RES<br />
CSNG - COMP SPECT GAMMA UKRT CSNG RATIO URANIUM POTASSIUM UKRT RES<br />
CSNG - COMP SPECT GAMMA URAN PPM PPM URANIUM URAN ppm ppm RES<br />
CSNG - COMP SPECT GAMMA SRAT SELECTED RATIO SRAT RES<br />
Mnemonics 9-7<br />
Type_<br />
Data
Serv_Name<br />
CSNG - COMP SPECT GAMMA FRMI FRAMES PER DEPTH INCRAMENT FRMINC RES<br />
CSNG - COMP SPECT GAMMA CCL CSNG CCL INPUT CCL INP<br />
CSNG - COMP SPECT GAMMA CSPC CSNG DISPLAY SPECTRUM CSPC RES<br />
CSNG - COMP SPECT GAMMA CTIM ACCUMULATION TIME C_TIME TEL<br />
CSNG - COMP SPECT GAMMA DERR CSNG FRAME DATA ERROR DATERR INP<br />
CSNG - COMP SPECT GAMMA ERPO % % ERROR POTASSIUM ERPO % % RES<br />
CSNG - COMP SPECT GAMMA ERTH PPM PPM ERROR THORIUM ERTH ppm ppm RES<br />
CSNG - COMP SPECT GAMMA ERUR PPM PPM ERROR URANIUM ERUR ppm ppm RES<br />
CSNG - COMP SPECT GAMMA FAVG AVERAGE FRAME TIME FRMAVG RES<br />
CSNG - COMP SPECT GAMMA GRUR GAPI GAPI GAMMA URANIUM GRUR gAPI gAPI RES<br />
CSNG - COMP SPECT GAMMA FRCT CSNG SPECTRAL FRAME COUNTER FRMCNT TEL<br />
CSNG - COMP SPECT GAMMA GRTO GAPI GAPI TOTAL GAMMA (150 KEV - 3 MEV) GRTO gAPI gAPI RES<br />
CSNG - COMP SPECT GAMMA FTIM MSEC MSEC FRAME TIME FTIME MSEC MSEC RES<br />
CSNG - COMP SPECT GAMMA GKCL GAPI GAPI GAMMMA KCL GKCL gAPI gAPI RES<br />
CSNG - COMP SPECT GAMMA GKUT GAPI GAPI GAMMA KUT GKUT gAPI gAPI RES<br />
CSNG - COMP SPECT GAMMA GRHI GAPI GAPI OBSERVED GAMMA (500KEV - 3MEV) GRHI gAPI gAPI RES<br />
CSNG - COMP SPECT GAMMA GRK GAPI GAPI GAMMA POTASSIUM GRK gAPI gAPI RES<br />
CSNG - COMP SPECT GAMMA GRKC GAPI GAPI GAMMMA KCL CORRECTED GRKC gAPI gAPI RES<br />
CSNG - COMP SPECT GAMMA GRKT GAPI GAPI GAMMA KT GRKT gAPI gAPI RES<br />
CSNG - COMP SPECT GAMMA AMCR CPS CPS AMERICIUM COUNTS AMCR 1.0/S 1.0/S RES<br />
CSNG - COMP SPECT GAMMA FERR FIT ERROR FERR RES<br />
CSNG - COMP SPECT GAMMA BORQ BORQ BORQ RES<br />
CSNG - COMP SPECT GAMMA MNGR MIN GAMMA RAY TOTAL ERROR MNGR RES<br />
CSNG - COMP SPECT GAMMA MNHB MIN BH POTASSIUM RUN AVG MNHB RES<br />
CSNG - COMP SPECT GAMMA MNKT MIN GAMMA RAY KT ERROR MNKT RES<br />
CSNG - COMP SPECT GAMMA MXBK MAX BH K CONCENT ERROR MXBK RES<br />
CSNG - COMP SPECT GAMMA MXGR MAX GAMMA RAY TOTAL MXGR RES<br />
CSNG - COMP SPECT GAMMA MXHB MAX BH POTASSIUM RUN AVG MXHB RES<br />
CSNG - COMP SPECT GAMMA MXKT MAX GAMMA RAY KT ERROR MKKT RES<br />
CSNG - COMP SPECT GAMMA MNBK MIN BH K CONCENT ERROR MNBK RES<br />
DH TENSION DLOD LB KG DOWNHOLE TENSION (HDTD) DLOD lbm Kg RES<br />
DH TENSION TEM2 DEGF DEGC BOREHOLE TEMPERATURE TEM2 degF degC RES<br />
DH TENSION PLOC DEG DEG PAD LOCATOR (HDTD) PLOC deg deg RES<br />
DLLT- DUAL LATERLOG LLS OHMM OHMM LATEROLOG SHALLOW RESISTIVITY LLS ohm.m ohm.m RES<br />
DLLT- DUAL LATERLOG CLLD MMHO MS-M LATEROLOG DEEP CONDUCTIVITY CLLD 0.001/ohm mS.m RES<br />
DLLT- DUAL LATERLOG DI IN IN DIAMETER OF INVASION DI RES<br />
DLLT- DUAL LATERLOG LLDC OHMM OHMM LLD CORRECTED LLDC RES<br />
DLLT- DUAL LATERLOG LLSC OHMM OHMM LLS CORRECTED LLSC RES<br />
DLLT- DUAL LATERLOG RT OHMM OHMM TRUE RESISTIVITY RT RES<br />
DLLT- DUAL LATERLOG RX0 OHMM OHMM FLUSHED ZONE RESISTIVITY RX0 RES<br />
DLLT- DUAL LATERLOG LLD OHMM OHMM LATEROLOG DEEP RESISTIVITY LLD ohm.m ohm.m RES<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
NPRS DECP DECP HDSN PRESSURE POROSITY CORR NPRS 100 pu 100 pu RES<br />
MCOR DECP DECP DSEN MUD POROSITY CORRECTION MCOR 100 pu 100 pu RES<br />
NPHS DECP DECP NEUTRON POROSITY SANDSTONE NPHS 100 pu 100 pu RES<br />
NBHC DECP DECP HDSN BOREHOLE POROSITY CORR NBHC 100 pu 100 pu RES<br />
NBHL DECP DECP HDSN BAD HOLE POROSITY CORR NBHL 100 pu 100 pu RES<br />
9-8 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
NCSG DECP DECP HDSN CASING POROSITY CORR NCSG 100 pu 100 pu RES<br />
NDNU CPS CPS HOSTILE DSN NEAR COUNTS UNFILT NDNU 1.0/S 1.0/S RES<br />
ADPE DECP DECP DSEN AIR DOLO POROSITY EVR ADPE 100 pu 100 pu RES<br />
NDSE DSNE NEAR SPACED COUNTS NDSE TEL<br />
NDSN CPS CPS DSN NEAR COUNTS NDSN 1.0/S 1.0/S RES<br />
RNDS COUNTS COUNTS RAW DSN II NEAR COUNTS NDSN COUNTS COUNTS TEL<br />
NPSO DECP DECP HDSN STANDOFF POROSITY CORR NPSO 100 pu 100 pu RES<br />
FDSN CPS CPS DSN FAR COUNTS FDSN 1.0/S 1.0/S RES<br />
NRAT C/C C/C DSN (NDSN/FDSN) RATIO NRAT C/C C/C RES<br />
ENPH DECP DECP DSEN LIQUID POROSITY ENPH 100 pu 100 pu RES<br />
NTMP DECP DECP HDSN TEMPERATURE POROSITY CORR NTMP 100 pu 100 pu RES<br />
NTOT DECP DECP HDSN TOTAL POROSITY CORR NTOT 100 pu 100 pu RES<br />
RFDS COUNTS COUNTS RAW DSN II FAR COUNTS FDSN COUNTS COUNTS TEL<br />
NLIM DECP DECP NEUTRON PHI LIME MATRIX NLIM 100 pu 100 pu RES<br />
NPHD DECP DECP NEUTRON POROSITY DOLOMITE NPHD 100 pu 100 pu RES<br />
ENDS CPS CPS DSN NEAR COUNTS - EVR ENDSN 1.0/S 1.0/S RES<br />
EAPH DECP DECP DSEN AIR POROSITY EAPH 100 pu 100 pu RES<br />
LDPE DECP DECP DSEN LIQUID DOLO POROSITY EVR LDPE 100 pu 100 pu RES<br />
LLP DECP DECP DSEN LIQUID LIME POROSITY LLP 100 pu 100 pu RES<br />
LLPE DECP DECP DSEN LIQUID LIME POROSITY EVR LLPE 100 pu 100 pu RES<br />
LSP DECP DECP DSEN LIQUID SAND POROSITY LSP 100 pu 100 pu RES<br />
LSPE DECP DECP DSEN LIQUID SAND POROSITY EVR LSPE 100 pu 100 pu RES<br />
LPHI DECP DECP DSEN LIQUID POROSITY LPHI 100 pu 100 pu RES<br />
EMPH DECP DECP MEAN OF NEAR/FAR AIR POROSTIY EMPH 100 pu 100 pu RES<br />
ELPH DECP DECP DSEN AIR POROSITY LONG ELPH 100 pu 100 pu RES<br />
ENRA C/C C/C DSN (NDSN/FDSN) RATIO - EVR ENRAT C/C C/C RES<br />
EFDS CPS CPS DSN FAR COUNTS - EVR EFDSN 1.0/S 1.0/S RES<br />
FDSE DSEN FAR SPACED COUNTS FDSE TEL<br />
ASPE DECP DECP DSEN AIR SAND POROSITY EVR ASPE 100 pu 100 pu RES<br />
NPHI DECP DECP NEUTRON POROSITY NPHI 100 pu 100 pu RES<br />
ENLI DECP DECP NEUTRON PHI LIME MATRIX - EVR ENLIM 100 pu 100 pu RES<br />
ALPE DECP DECP DSEN AIR LIME POROSITY EVR ALPE 100 pu 100 pu RES<br />
ENPD DECP DECP NEUTRON POROSITY DOLOMITE EVR ENPHD 100 pu 100 pu RES<br />
Mnemonics 9-9<br />
Type_<br />
Data
Serv_Name<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
DSN/DSEN - DUAL SPACE<br />
NEUTRON<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
LDP DECP DECP DSEN LIQUID DOLO POROSITY LDP 100 pu 100 pu RES<br />
ENPS DECP DECP NEUTRON POROSITY SAND EVR ENPHS 100 pu 100 pu RES<br />
ETCO EVR TOTAL CORRECTION ETCOR RES<br />
FDNU CPS CPS HOSTILE DSN FAR COUNTS UNFILT FDNU 1.0/S 1.0/S RES<br />
EMI - ELECT MICRO IMAGING ACYU G G ACCELEROMETER Y UNFILTERED ACYU G G INP<br />
EMI - ELECT MICRO IMAGING EDD2 OHMM OHMM PAD #2 RESISTIVITY (FAST) EDD2 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING CALA IN MM EMI AVERAGE CALIPER CALA in mm RES<br />
EMI - ELECT MICRO IMAGING DCAL IN MM EMI DIFFERENTIAL CALIPER DCAL in mm RES<br />
EMI - ELECT MICRO IMAGING DEVI DEG DEG DRIFT ANGLE DEVI deg deg RES<br />
EMI - ELECT MICRO IMAGING DMAX IN MM EMI MAXIMUM CALIPER PAIR DMAX in mm RES<br />
EMI - ELECT MICRO IMAGING DMIN IN MM EMI MINIMUM CALIPER PAIR DMIN in mm RES<br />
EMI - ELECT MICRO IMAGING DXT2 08.3MS 08.3MS Z ACCELEROMETER (FAST) TIME DXT2 8.3 mS 8.3 mS RES<br />
EMI - ELECT MICRO IMAGING ACCZ G G ACCELEROMETER Z-AXIS ACCZ G G RES<br />
EMI - ELECT MICRO IMAGING EDD1 OHMM OHMM PAD #1 RESISTIVITY (FAST) EDD1 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING CAL4 IN MM EMI CALIPER ARM #4 (DIAMETER) CAL4 in mm RES<br />
EMI - ELECT MICRO IMAGING EDD3 OHMM OHMM PAD #3 RESISTIVITY (FAST) EDD3 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING EDD4 OHMM OHMM PAD #4 RESISTIVITY (FAST) EDD4 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING EDD5 OHMM OHMM PAD #5 RESISTIVITY (FAST) EDD5 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING EDD6 OHMM OHMM PAD #6 RESISTIVITY (FAST) EDD6 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING EMIM EMI TOOL MODE EMIM INP<br />
EMI - ELECT MICRO IMAGING EMMR VOLT VOLT REAL PART PHASOR VOLTAGE EMMR V V INP<br />
EMI - ELECT MICRO IMAGING DXTM 08.3MS 08.3MS Z ACCELEROMETER (FAST) TIME DXTM 8.3 mS 8.3 mS RES<br />
EMI - ELECT MICRO IMAGING BHVT FT3 M3 BOREHOLE VOLUME TOTAL BHVT ft3 m3 RES<br />
EMI - ELECT MICRO IMAGING ACCX G G ACCELEROMETER X-AXIS ACCX G G RES<br />
EMI - ELECT MICRO IMAGING ACCY G G ACCELEROMETER Y-AXIS ACCY G G RES<br />
EMI - ELECT MICRO IMAGING ACXU G G ACCELEROMETER X UNFILTERED ACXU G G INP<br />
EMI - ELECT MICRO IMAGING ACZU G G ACCELEROMETER Z UNFILTERED ACZU G G INP<br />
EMI - ELECT MICRO IMAGING AHV FT3 M3 ANNULAR HOLE VOLUME MARK AHV ft3 m3 RES<br />
EMI - ELECT MICRO IMAGING AHVT FT3 M3 ANNULAR HOLE VOLUME TOTAL AHVT ft3 m3 RES<br />
EMI - ELECT MICRO IMAGING CAL6 IN MM EMI CALIPER ARM #6 (DIAMETER) CAL6 in mm RES<br />
EMI - ELECT MICRO IMAGING BHV FT3 M3 BOREHOLE VOLUME MARK BHV ft3 m3 RES<br />
EMI - ELECT MICRO IMAGING CAL5 IN MM EMI CALIPER ARM #5 (DIAMETER) CAL5 in mm RES<br />
EMI - ELECT MICRO IMAGING C14 IN MM EMI CALIPER PAIR 1-4 C14 in mm RES<br />
EMI - ELECT MICRO IMAGING C25 IN MM EMI CALIPER PAIR 2-5 C25 in mm RES<br />
EMI - ELECT MICRO IMAGING C36 IN MM EMI CALIPER PAIR 3-6 C36 in mm RES<br />
EMI - ELECT MICRO IMAGING CAL1 IN MM EMI CALIPER ARM #1 (DIAMETER) CAL1 in mm RES<br />
EMI - ELECT MICRO IMAGING CAL2 IN MM EMI CALIPER ARM #2 (DIAMETER) CAL2 in mm RES<br />
EMI - ELECT MICRO IMAGING CAL3 IN MM EMI CALIPER ARM #3 (DIAMETER) CAL3 in mm RES<br />
EMI - ELECT MICRO IMAGING ACCQ ACCELEROMETER SUM OF SQUARES ACCQ RES<br />
EMI - ELECT MICRO IMAGING AZI1 DEG DEG PAD #1 AZIMUTH AZI1 deg deg RES<br />
EMI - ELECT MICRO IMAGING MAGZ MAGNETOMETER Z-AXIS MAGZ RES<br />
EMI - ELECT MICRO IMAGING P4B1 OHMM OHMM PAD #4 RESISTIVITY P4B1 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING ITMP DEGF DEGC INTERNAL TEMPERATURE ITMP degF degC RES<br />
EMI - ELECT MICRO IMAGING LOWS DEG DEG LOW SIDE OF HOLE LOSIDE deg deg RES<br />
EMI - ELECT MICRO IMAGING MAGQ MAGNETOMETER SUM OF SQUARES MAGQ RES<br />
EMI - ELECT MICRO IMAGING MAGX MAGNETOMETER X-AXIS MAGX RES<br />
EMI - ELECT MICRO IMAGING F6B1 SED PAD #6, PROFILE 1 (FAST) F6B1 RES<br />
9-10 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
EMI - ELECT MICRO IMAGING MAGY MAGNETOMETER Y-AXIS MAGY RES<br />
EMI - ELECT MICRO IMAGING F5B1 SED PAD #5, PROFILE 1 (FAST) F5B1 RES<br />
EMI - ELECT MICRO IMAGING MGXU MAGNETOMETER X UNFILTERED MGXU INP<br />
EMI - ELECT MICRO IMAGING MGYU MAGNETOMETER Y UNFILTERED MGYU INP<br />
EMI - ELECT MICRO IMAGING MGZU MAGNETOMETER Z UNFILTERED MGZU INP<br />
EMI - ELECT MICRO IMAGING P1B1 OHMM OHMM PAD #1 RESISTIVITY P1B1 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING P2B1 OHMM OHMM PAD #2 RESISTIVITY P2B1 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING RB DEG DEG PAD #1 ROTATION RB deg deg RES<br />
EMI - ELECT MICRO IMAGING RAD6 IN MM EMI CALIPER ARM #6 (RADIUS) RAD6 in mm RES<br />
EMI - ELECT MICRO IMAGING ERD4 OHMM OHMM PAD #4 RESISTIVITY FAST UNDELY ERD4 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING BTOT TOAL MAGNETIC FIELD - NAV TOOL BTOT RES<br />
EMI - ELECT MICRO IMAGING GTOT TOAL GRAVITY FIELD - NAV TOOL GTOT RES<br />
EMI - ELECT MICRO IMAGING HDIA MEASURED HOLE DIAMETER HDIA RES<br />
EMI - ELECT MICRO IMAGING TLFC TOOL FACE DIRECTION TLFC RES<br />
EMI - ELECT MICRO IMAGING ERD1 OHMM OHMM PAD #1 RESISTIVITY FAST UNDELY ERD1 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING HAZI DEG DEG DRIFT AZIMUTH HAZI deg deg RES<br />
EMI - ELECT MICRO IMAGING ERD3 OHMM OHMM PAD #3 RESISTIVITY FAST UNDELY ERD3 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING P5B1 OHMM OHMM PAD #5 RESISTIVITY P5B1 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING ERD5 OHMM OHMM PAD #5 RESISTIVITY FAST UNDELY ERD5 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING ERD6 OHMM OHMM PAD #6 RESISTIVITY FAST UNDELY ERD6 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING F1B1 SED PAD #1, PROFILE 1 (FAST) F1B1 RES<br />
EMI - ELECT MICRO IMAGING F2B1 SED PAD #2, PROFILE 1 (FAST) F2B1 RES<br />
EMI - ELECT MICRO IMAGING F3B1 SED PAD #3, PROFILE 1 (FAST) F3B1 RES<br />
EMI - ELECT MICRO IMAGING F4B1 SED PAD #4, PROFILE 1 (FAST) F4B1 RES<br />
EMI - ELECT MICRO IMAGING ERD2 OHMM OHMM PAD #2 RESISTIVITY FAST UNDELY ERD2 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING RAD5 IN MM EMI CALIPER ARM #5 (RADIUS) RAD5 in mm RES<br />
EMI - ELECT MICRO IMAGING RHOC OHMM OHMM BHC CORR. RESISTIVITY RHOC ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING TEMP DEGC DEGC NAVIGATION TEMPERATURE TEMP degC degC RES<br />
EMI - ELECT MICRO IMAGING ZAC2 G G Z ACCELEROMETER (FAST) ZAC2 G G RES<br />
EMI - ELECT MICRO IMAGING ZACC G G Z ACCELEROMETER (FAST) ZACC G G RES<br />
EMI - ELECT MICRO IMAGING P3B1 OHMM OHMM PAD #3 RESISTIVITY P3B1 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING EMMX VOLT VOLT IMAGINARY PART PHASOR VOLTAGE EMMX V V INP<br />
EMI - ELECT MICRO IMAGING RHOA OHMM OHMM AVERAGE RESISTIVITY RHOA ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING RAD4 IN MM EMI CALIPER ARM #4 (RADIUS) RAD4 in mm RES<br />
EMI - ELECT MICRO IMAGING RAD3 IN MM EMI CALIPER ARM #3 (RADIUS) RAD3 in mm RES<br />
EMI - ELECT MICRO IMAGING RAD2 IN MM EMI CALIPER ARM #2 (RADIUS) RAD2 in mm RES<br />
EMI - ELECT MICRO IMAGING PRES EMI PAD FORCE PRES RES<br />
EMI - ELECT MICRO IMAGING PDDV V V EMI RELATIVE PAD VOLTAGE PDDV V V RES<br />
EMI - ELECT MICRO IMAGING PADS NESW NESW VIEW BUTTONS IMAGE (N-E-S-W-N) PADS NESW NESW RES<br />
EMI - ELECT MICRO IMAGING PAD6 PAD #6 - FAST DATA ARRAY PAD6 INP<br />
EMI - ELECT MICRO IMAGING PAD5 PAD #5 - FAST DATA ARRAY PAD5 INP<br />
EMI - ELECT MICRO IMAGING PAD4 PAD #4 - FAST DATA ARRAY PAD4 INP<br />
EMI - ELECT MICRO IMAGING P6B1 OHMM OHMM PAD #6 RESISTIVITY P6B1 ohm.m ohm.m RES<br />
EMI - ELECT MICRO IMAGING PAD1 PAD #1 - FAST DATA ARRAY PAD1 INP<br />
EMI - ELECT MICRO IMAGING RAD1 IN MM EMI CALIPER ARM #1 (RADIUS) RAD1 in mm RES<br />
EMI - ELECT MICRO IMAGING PAD2 PAD #2 - FAST DATA ARRAY PAD2 INP<br />
EMI - ELECT MICRO IMAGING PAD3 PAD #3 - FAST DATA ARRAY PAD3 INP<br />
FCMT - FORM COMP MONITOR RGR1 CPS CPS RAW GAMMA RAY 1 RGR1 1.0/S 1.0/S RES<br />
FCMT - FORM COMP MONITOR ACCZ ACCELEROMETER ACCZ RES<br />
Mnemonics 9-11<br />
Type_<br />
Data
Serv_Name<br />
FCMT - FORM COMP MONITOR CCL CCL FOR CORRELATION CCL RES<br />
FCMT - FORM COMP MONITOR CCL1 RAW COLLAR LOCATOR 1 CCL1 RES<br />
FCMT - FORM COMP MONITOR CCL2 RAW COLLAR LOCATOR 2 CCL2 RES<br />
FCMT - FORM COMP MONITOR TEMP DEGF DEGC INTERNAL TOOL TEMPERATURE TEMP degF degC RES<br />
FCMT - FORM COMP MONITOR GR API API GAMMA RAY GR gAPI gAPI RES<br />
FCMT - FORM COMP MONITOR RGR3 CPS CPS RAW GAMMA RAY 3 RGR3 1.0/S 1.0/S RES<br />
FCMT - FORM COMP MONITOR RGR2 CPS CPS RAW GAMMA RAY 2 RGR2 1.0/S 1.0/S RES<br />
FCMT - FORM COMP MONITOR DXTM CPS CPS ACCELEROMETER TIME DXTM 1.0/S 1.0/S RES<br />
FCMT - FORM COMP MONITOR RGR4 CPS CPS RAW GAMMA RAY 4 RGR4 1.0/S 1.0/S RES<br />
FIAC - FOUR INDEP ARM<br />
CALIPER<br />
FIAC - FOUR INDEP ARM<br />
CALIPER<br />
FIAC - FOUR INDEP ARM<br />
CALIPER<br />
FIAC - FOUR INDEP ARM<br />
CALIPER<br />
FIAC - FOUR INDEP ARM<br />
CALIPER<br />
FIAC - FOUR INDEP ARM<br />
CALIPER<br />
FIAC - FOUR INDEP ARM<br />
CALIPER<br />
FIAC - FOUR INDEP ARM<br />
CALIPER<br />
FIAC - FOUR INDEP ARM<br />
CALIPER<br />
FIAC - FOUR INDEP ARM<br />
CALIPER<br />
FIAC - FOUR INDEP ARM<br />
CALIPER<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
SO3 IN MM STAND OFF ARM 3 STAND3 in mm RES<br />
SO4 IN MM STAND OFF ARM 4 STAND4 in mm RES<br />
SO2 IN MM STAND OFF ARM 2 STAND2 in mm RES<br />
SO1 IN MM STAND OFF ARM 1 STAND1 in mm RES<br />
CALA IN MM AVERAGE CALIPER (C1+C2)/2 CALA in mm RES<br />
CAL4 IN MM CALIPER 4 CAL4 in mm RES<br />
CAL2 IN MM CALIPER 2 CAL2 in mm RES<br />
CAL1 IN MM CALIPER 1 CAL1 in mm RES<br />
C24 IN MM FOUR ARM CALIPER ARMS 2 & 4 C24 in mm RES<br />
C13 IN MM FOUR ARM CALIPER ARMS 1 & 3 C13 in mm RES<br />
CAL3 IN MM CALIPER 3 CAL3 in mm RES<br />
FWST - FULL WAVE SONIC AMPL DB DB AMPLITUDE AMPL dB dB RES<br />
FWST - FULL WAVE SONIC ITT INTEGRATED TRAVEL TIME MARK ITT RES<br />
FWST - FULL WAVE SONIC GFAR FAR RECEIVER GAIN GAIN_F INP<br />
FWST - FULL WAVE SONIC FNOI FAR RECEIVER NOISE FNOISE INP<br />
FWST - FULL WAVE SONIC ERR ERROR ERROR INP<br />
FWST - FULL WAVE SONIC DTXM DELTA T AT TRANSMITTER DT_XMT INP<br />
FWST - FULL WAVE SONIC DTUN DELTA T UNFILTERED DT_UNF INP<br />
FWST - FULL WAVE SONIC ALPH ALPHA ALPHA INP<br />
FWST - FULL WAVE SONIC DT US/F US/M DELTA TIME COMPRESSIVE DT uS/ft US/M RES<br />
FWST - FULL WAVE SONIC ALPH ALPHA ALPHA INP<br />
FWST - FULL WAVE SONIC MSGR MSG RECEIVER MSGRCV INP<br />
FWST - FULL WAVE SONIC ITTT INTEGRATED TRAVEL TIME TOTAL ITTT RES<br />
FWST - FULL WAVE SONIC DTRC DELTA T AT RECEIVER DT_RCV INP<br />
FWST - FULL WAVE SONIC TT1 US US NEAR TRAVEL TIME TT1 uS uS RES<br />
FWST - FULL WAVE SONIC NNOI NEAR RECEIVER NOISE NNOISE INP<br />
FWST - FULL WAVE SONIC WFMS FWST MSG WAVEFORM WFMSG INP<br />
FWST - FULL WAVE SONIC WFFW MONOPOLE WF; ONE OF TWO WF'S. WFMT TEL<br />
FWST - FULL WAVE SONIC GNEA NEAR RECEIVER GAIN GAIN_N INP<br />
FWST - FULL WAVE SONIC TT2 US US FAR TRAVEL TIME TT2 uS uS RES<br />
FWST - FULL WAVE SONIC SPHI DECP DECP SONIC POROSITY SPHI 100 pu 100 pu RES<br />
FWST - FULL WAVE SONIC SDT2 US/F US/M DELTA T (2 FOOT) SDT2 uS/ft US/M RES<br />
FWST - FULL WAVE SONIC QDT DELTA TIME QUALITY QDT RES<br />
FWST - FULL WAVE SONIC PKCD PICK CODE PKCODE INP<br />
FWST - FULL WAVE SONIC WFFW HFWS FULL WAVE WAVEFORMS WFFW INP<br />
9-12 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
GTET-GAMMA TELEMETRY ACCZ G G ACCELEROMETER Z-AXIS ACCZ G G RES<br />
GTET-GAMMA TELEMETRY EGR GAMMA RAY - EVR EGR RES<br />
GTET-GAMMA TELEMETRY INCL DEG DEG INCLINATION INCL deg deg RES<br />
GTET-GAMMA TELEMETRY GR GAMMA RAY GR RES<br />
HDIL - HOSTILE DUAL IND RES ILM OHMM OHMM INDUCTION MEDIUM RESISTIVITY ILM ohm.m ohm.m RES<br />
HDIL - HOSTILE DUAL IND RES SP MV MV SP SP mV mV RES<br />
HDIL - HOSTILE DUAL IND RES ILD OHMM OHMM INDUCTION DEEP RESISTIVITY ILD ohm.m ohm.m RES<br />
HDIL - HOSTILE DUAL IND RES CILD MMHO MS-M DEEP INDUCTION CONDUCTIVITY CILD 0.001/ohm mS.m RES<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
FE23 DIFF DIELECTRIC CONST 12 17 CM FE23 RES<br />
FE13 DIFF DIELECTRIC CONST 8 17 CM FE13 RES<br />
FE12 DIFF DIELECTRIC CONST 8 12 CM FE12 RES<br />
FDB3 DB DB AMPLITUDE 17 CM RECEIVER FDB3 dB dB RES<br />
FDB2 DB DB AMPLITUDE 12 CM RECEIVER FDB2 dB dB RES<br />
FDB1 DB DB AMPLITUDE 8 CM RECEIVER FDB1 dB dB RES<br />
FD23 DB DB DIFF AMPLITUDE 12 17 CM RCVR FD23 dB dB RES<br />
FET2 DIELECTRIC CONSTANT 12 CM FET2 RES<br />
FD13 DB DB DIFF AMPLITUDE 8 17 CM RCVR FD13 dB dB RES<br />
FET3 DIELECTRIC CONST 17 CM FET3 RES<br />
FET1 DIELECTRIC CONSTANT 8 CM FET1 RES<br />
MP1V MINUS .1 VOLT MP1V TEL<br />
FTPL NS/M NS/M HFDT TRAVEL TIME FTPL NS/M NS/M RES<br />
GR16 GROUND 16 GR16 TEL<br />
GR64 GROUND 64 GR64 TEL<br />
GRD1 GROUND 1 GRD1 TEL<br />
GRD4 GROUND 4 GRD4 TEL<br />
HSTA HFDT TOOL STATUS HSTA TEL<br />
IMLA MICROLOG LATERAL IMLA TEL<br />
IMNO MICROLOG NORMAL IMNO TEL<br />
ITEM RAW TEMPERATURE ITEM TEL<br />
ITMP HFDT TEMPERATURE TEMP INP<br />
FETR TRANS. DIELECTRIC R FETR RES<br />
M8V MINUS 8. VOLT M8V TEL<br />
FRPY HFDT REFELECTED POWER Y FRPY TEL<br />
MP5V MINUS .5 VOLT MP5V TEL<br />
P2V POSITIVE 2 VOLT P2V TEL<br />
Mnemonics 9-13<br />
Type_<br />
Data
Serv_Name<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
P8V POSITIVE 8 VOLT P8V TEL<br />
PP1V POSITIVE .1 VOLT PP1V TEL<br />
PP5V POSITIVE .5 VOLT PP5V TEL<br />
RACZ HFDT Z-ACCELEROMETER RAW RACZ TEL<br />
RAD1 CALIPER 1 RAD1 TEL<br />
RAD2 CALIPER 2 RAD2 TEL<br />
TEM2 DSTU TEMPERATURE (F) DSTEMP TEL<br />
TPL NS/M NS/M HFDT TRAVEL TIME - LO RES FTPL25 NS/M NS/M RES<br />
ZACC ACCZ CALIBRATED INPUT FAST ZACC INP<br />
M2V MINUS 2. VOLT M2V TEL<br />
FR1Y HFDT REC. #1 Y COMPONENT FR1Y TEL<br />
FPH1 DEGREE DEGREE PHASE 8 CM RECEIVER FPH1 deg deg RES<br />
FIPY HFDT INCIDENT POWER Y FIPY TEL<br />
FP12 DEGREE DEGREE DIFF PHASE 8 12CM RECEIVER FP12 deg deg RES<br />
FP13 DEGREE DEGREE DIFF PHASE 8 17CM RECEIVER FP13 deg deg RES<br />
FP23 DEGREE DEGREE DIFF PHASE 12 17CM RECEIVER FP23 deg deg RES<br />
FPH2 DEGREE DEGREE PHASE 12 CM RECEIVER FPH2 deg deg RES<br />
FPHX DECP DECP HFDT POROSITY FPHX 100 pu 100 pu RES<br />
FPHY HFDT QUALITY FPHY RES<br />
FR1 OHMM OHMM RESISTIVITY 8 CM FR1 ohm.m ohm.m RES<br />
FR12 OHMM OHMM DIFF RESISTIVITY 8 12 CM FR12 ohm.m ohm.m RES<br />
FR13 OHMM OHMM DIFF RESISTIVITY 8 17CM FR13 ohm.m ohm.m RES<br />
FT25 NS/M NS/M HFDT TRAVEL TIME - LO RES FTPL25 NS/M NS/M RES<br />
FR1X HFDT REC. #1 X COMPONENT FR1X TEL<br />
FRTR OHMM OHMM TRANS. RESISTIVITY FRTR ohm.m ohm.m RES<br />
FR2 OHMM OHMM RESISTIVITY 12 CM FR2 ohm.m ohm.m RES<br />
FR23 OHMM OHMM DIFF RESISTIVITY 12 17CM FR23 ohm.m ohm.m RES<br />
FR2G HFDT REC. #2 GAIN FR2G TEL<br />
FR2X HFDT REC. #2 X COMPONENT FR2X TEL<br />
FR2Y HFDT REC. #2 Y COMPONENT FR2Y TEL<br />
FR3 OHMM OHMM RESISTIVITY 17 CM FR3 ohm.m ohm.m RES<br />
FR3G HFDT REC. #3 GAIN FR3G TEL<br />
FR3X HFDT REC. #3 X COMPONENT FR3X TEL<br />
9-14 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HFDT - HI FREQ DIELECTRIC<br />
TOOL<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
FR3Y HFDT REC. #3 Y COMPONENT FR3Y TEL<br />
FRPX HFDT REFELECTED POWER X FRPX TEL<br />
FIPX HFDT INCIDENT POWER X FIPX TEL<br />
FR1G HFDT REC. #1 GAIN FR1G TEL<br />
AG1 AUX GROUND 1 AG1 TEL<br />
FPH3 DEGREE DEGREE PHASE 17 CM RECEIVER FPH3 deg deg RES<br />
AC DB/M DB/M ATTENUATION CORRECTED - LO RES FAC25 DB/M DB/M RES<br />
FD12 DB DB DIFF AMPLITUDE 8 12 CM RCVR FD12 dB dB RES<br />
AG16 AUX GROUND 16 AG16 TEL<br />
AG4 AUX GROUND 4 AG4 TEL<br />
AG64 AUX GROUND 64 AG64 TEL<br />
DXTM 08.3MS 08.3MS HFDT Z-ACCELEROMETER TIME BASE DXTM 8.3 mS 8.3 mS INP<br />
FA25 DB/M DB/M ATTENUATION CORRECTED - LO RES FAC25 DB/M DB/M RES<br />
FAC DB/M DB/M ATTENUATION CORRECTED FAC dB/m dB/m RES<br />
HF06 OHMM OHMM HRAI 60 IN RAD RESIST 4FT HF06 ohm.m ohm.m RES<br />
HMR HRI MEDIUM RAW R HMR RES<br />
HMCN MMHO MS-M HRI MEDIUM CONDUCTIVITY HMCN 0.001/ohm mS.m RES<br />
HMC1 MMHO MS-M HRI MEDIUM CONDUCTIVITY 1FT HMC1 0.001/ohm mS.m RES<br />
HF12 OHMM OHMM HRAI 120 IN RAD RESIST 4FT HF12 ohm.m ohm.m RES<br />
HF09 OHMM OHMM HRAI 90 IN RAD RESIST 4FT HF09 ohm.m ohm.m RES<br />
HMR1 OHMM OHMM HRI MEDIUM RESISTIVITY 1FT HMR1 ohm.m ohm.m RES<br />
HF03 OHMM OHMM HRAI 30 IN RAD RESIST 4FT HF03 ohm.m ohm.m RES<br />
HF02 OHMM OHMM HRAI 20 IN RAD RESIST 4FT HF02 ohm.m ohm.m RES<br />
HF01 OHMM OHMM HRAI 10 IN RAD RESIST 4FT HF01 ohm.m ohm.m RES<br />
HMRS OHMM OHMM HRI MEDIUM RESISTIVITY HMRS ohm.m ohm.m RES<br />
HDRS OHMM OHMM HRI DEEP RESISTIVITY HDRS ohm.m ohm.m RES<br />
HO09 OHMM OHMM HRAI 90 IN RAD RESIST 1FT HO09 ohm.m ohm.m RES<br />
HDR1 OHMM OHMM HRI DEEP RESISTIVITY 1FT HDR1 ohm.m ohm.m RES<br />
HDR HRI DEEP RAW R HDR RES<br />
HDX HRI DEEP RAW X HDX RES<br />
HO24 OHMM OHMM HRI DEEP RES 1FT 24 INCH I HO24 ohm.m ohm.m RES<br />
HRM1 HRI MAP - ONE FOOT HRM1 RES<br />
HRFX XMTR REF 32KHz X SIGNAL X32KRF INP<br />
Mnemonics 9-15<br />
Type_<br />
Data
Serv_Name<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
HRFR XMTR REF 32KHz R SIGNAL R32KRF INP<br />
HO90 OHMM OHMM HRI DEEP RES 1FT 90 INCH I HO90 ohm.m ohm.m RES<br />
HO60 OHMM OHMM HRI DEEP RES 1FT 60 INCH I HO60 ohm.m ohm.m RES<br />
HO03 OHMM OHMM HRAI 30 IN RAD RESIST 1FT HO03 ohm.m ohm.m RES<br />
HO30 OHMM OHMM HRI DEEP RES 1FT 30 INCH I HO30 ohm.m ohm.m RES<br />
HMX HRI MEDIUM RAW X HMX RES<br />
HO12 OHMM OHMM HRAI 120 IN RAD RESIST 1FT HO12 ohm.m ohm.m RES<br />
HD3R MMHO MMHO LOWER 54" RCVR 32KHz R SIGNAL HD3R 0.001/ohm 0.001/ohm INP<br />
HO06 OHMM OHMM HRAI 60 IN RAD RESIST 1FT HO06 ohm.m ohm.m RES<br />
HDCN MMHO MS-M HRI DEEP CONDUCTIVITY HDCN 0.001/ohm mS.m RES<br />
HO02 OHMM OHMM HRAI 20 IN RAD RESIST 1FT HO02 ohm.m ohm.m RES<br />
HO01 OHMM OHMM HRAI 10 IN RAD RESIST 1FT HO01 ohm.m ohm.m RES<br />
HO40 OHMM OHMM HRI DEEP RES 1FT 40 INCH I HO40 ohm.m ohm.m RES<br />
DSE2 MMHO MMHO SKIN EFFECT CORRECTIONS D3 DSE2 0.001/ohm 0.001/ohm RES<br />
DT18 OHMM OHMM AVG DECON 18" 2FT DT18 ohm.m ohm.m RES<br />
DSE9 MMHO MMHO SKIN EFFECT CORRECTIONS U1 DSE9 0.001/ohm 0.001/ohm RES<br />
DSE8 MMHO MMHO SKIN EFFECT CORRECTIONS U2 DSE8 0.001/ohm 0.001/ohm RES<br />
DSE7 MMHO MMHO SKIN EFFECT CORRECTIONS U3 DSE7 0.001/ohm 0.001/ohm RES<br />
DSE6 MMHO MMHO SKIN EFFECT CORRECTIONS U4 DSE6 0.001/ohm 0.001/ohm RES<br />
DSE5 MMHO MMHO SKIN EFFECT CORRECTIONS D6 DSE5 0.001/ohm 0.001/ohm RES<br />
HD4R MMHO MMHO LOWER 42" RCVR 32KHz R SIGNAL HD4R 0.001/ohm 0.001/ohm INP<br />
DSE3 MMHO MMHO SKIN EFFECT CORRECTIONS D4 DSE3 0.001/ohm 0.001/ohm RES<br />
DT54 OHMM OHMM AVG DECON 54" 2FT DT54 ohm.m ohm.m RES<br />
DSE1 MMHO MMHO SKIN EFFECT CORRECTIONS D2 DSE1 0.001/ohm 0.001/ohm RES<br />
DSE0 MMHO MMHO SKIN EFFECT CORRECTIONS D1 DSE0 0.001/ohm 0.001/ohm RES<br />
DRCO MMHO MMHO HRI DEEP R CORRECTION DRCO 0.001/ohm 0.001/ohm RES<br />
DQZE MMHO MMHO HRI DEEP QUALITY ZERO DQZER 0.001/ohm 0.001/ohm INP<br />
DQU9 MMHO MMHO QUALITY U1 DQU9 0.001/ohm 0.001/ohm RES<br />
DQU8 MMHO MMHO QUALITY U2 DQU8 0.001/ohm 0.001/ohm RES<br />
DSE4 MMHO MMHO SKIN EFFECT CORRECTIONS U5 DSE4 0.001/ohm 0.001/ohm RES<br />
HD1R MMHO MMHO LOWER 78" RVCR 32KHz R SIGNAL HD1R 0.001/ohm 0.001/ohm INP<br />
ZM DFL MEASURE Z ZM RES<br />
HD6R MMHO MMHO LOWER 18" RCVR 32KHz R SIGNAL HD6R 0.001/ohm 0.001/ohm INP<br />
9-16 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
HRM2 HRI MAP - TWO FOOT HRM2 RES<br />
HD3X MMHO MMHO LOWER 54" RCVR 32KHz X SIGNAL HD3X 0.001/ohm 0.001/ohm INP<br />
HT12 OHMM OHMM HRAI 120 IN RAD RESIST 2FT HT12 ohm.m ohm.m RES<br />
HD2X MMHO MMHO LOWER 69" RCVR 32KHz X SIGNAL HD2X 0.001/ohm 0.001/ohm INP<br />
DT30 OHMM OHMM AVG DECON 30" 2FT DT30 ohm.m ohm.m RES<br />
HD1X MMHO MMHO LOWER 78" RCVR 32KHz X SIGNAL HD1X 0.001/ohm 0.001/ohm INP<br />
DT42 OHMM OHMM AVG DECON 42" 2FT DT42 ohm.m ohm.m RES<br />
ECC ECCENTRICITY ECC RES<br />
DZM DFL MEASURE DELTA Z DZM RES<br />
DZB DFL BUCK DELTA Z DZB RES<br />
DXCO MMHO MMHO HRI DEEP X CORRECTION DXCO 0.001/ohm 0.001/ohm RES<br />
DT78 OHMM OHMM AVG DECON 78" 2FT DT78 ohm.m ohm.m RES<br />
DT69 OHMM OHMM AVG DECON 69" 2FT DT69 ohm.m ohm.m RES<br />
HDC1 MMHO MS-M HRI DEEP CONDUCTIVITY 1FT HDC1 0.001/ohm mS.m RES<br />
HD2R MMHO MMHO LOWER 69" RCVR 32KHz R SIGNAL HD2R 0.001/ohm 0.001/ohm INP<br />
LSO LEFT STANDOFF LSO RES<br />
LD4R MMHO MMHO LOWER 42" RCVR 8 KHz R SIGNAL LD4R 0.001/ohm 0.001/ohm INP<br />
LD4X MMHO MMHO LOWER 42" RCVR 8 KHz X SIGNAL LD4X 0.001/ohm 0.001/ohm INP<br />
LD6R MMHO MMHO LOWER 18" RCVR 8 KHz R SIGNAL LD6R 0.001/ohm 0.001/ohm INP<br />
LD6X MMHO MMHO LOWER 18" RCVR 8 KHz X SIGNAL LD6X 0.001/ohm 0.001/ohm INP<br />
LMAN LEFT MANDREL LMAN RES<br />
HT06 OHMM OHMM HRAI 60 IN RAD RESIST 2FT HT06 ohm.m ohm.m RES<br />
LRFX XMTR REF 8 KHz X SIGNAL X8KREF INP<br />
LD2X MMHO MMHO LOWER 69" RCVR 8 KHz X SIGNAL LD2X 0.001/ohm 0.001/ohm INP<br />
LU1R MMHO MMHO UPPER 78" RCVR 8 KHz R SIGNAL LU1R 0.001/ohm 0.001/ohm INP<br />
LU1X MMHO MMHO UPPER 78" RCVR 8 HKz X SIGNAL LU1X 0.001/ohm 0.001/ohm INP<br />
LU2R MMHO MMHO UPPER 69" RCVR 8 KHz R SIGNAL LU2R 0.001/ohm 0.001/ohm INP<br />
LU2X MMHO MMHO UPPER 69" RCVR 8 KHz X SIGNAL LU2X 0.001/ohm 0.001/ohm INP<br />
LU3R MMHO MMHO UPPER 54" RCVR 8 KHz R SIGNAL LU3R 0.001/ohm 0.001/ohm INP<br />
LU3X MMHO MMHO UPPER 54" RCVR 8 KHz X SIGNAL LU3X 0.001/ohm 0.001/ohm INP<br />
LRFR XMTR REF 8 KHz R SIGNAL R8KREF INP<br />
HD4X MMHO MMHO LOWER 42" RCVR 32KHz X SIGNAL HD4X 0.001/ohm 0.001/ohm INP<br />
HU1X MMHO MMHO UPPER 78" RCVR 32KHz X SIGNAL HU1X 0.001/ohm 0.001/ohm INP<br />
Mnemonics 9-17<br />
Type_<br />
Data
Serv_Name<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
HU2R MMHO MMHO UPPER 69" RCVR 32KHz R SIGNAL HU2R 0.001/ohm 0.001/ohm INP<br />
HU2X MMHO MMHO UPPER 69" RCVR 32KHz X SIGNAL HU2X 0.001/ohm 0.001/ohm INP<br />
HU3R MMHO MMHO UPPER 54" RCVR 32KHz R SIGNAL HU3R 0.001/ohm 0.001/ohm INP<br />
HU3X MMHO MMHO UPPER 54" RCVR 32KHz X SIGNAL HU3X 0.001/ohm 0.001/ohm INP<br />
HU4R MMHO MMHO UPPER 42" RCVR 32KHz R SIGNAL HU4R 0.001/ohm 0.001/ohm INP<br />
LD3X MMHO MMHO LOWER 54" RCVR 8 KHz X SIGNAL LD3X 0.001/ohm 0.001/ohm INP<br />
HU5R MMHO MMHO UPPER 30" RCVR 32KHz R SIGNAL HU5R 0.001/ohm 0.001/ohm INP<br />
LD3R MMHO MMHO LOWER 54" RCVR 8 KHz R SIGNAL LD3R 0.001/ohm 0.001/ohm INP<br />
HU5X MMHO MMHO UPPER 30" RCVR 32KHz X SIGNAL HU5X 0.001/ohm 0.001/ohm INP<br />
DQU7 MMHO MMHO QUALITY U3 DQU7 0.001/ohm 0.001/ohm RES<br />
LD1R MMHO MMHO LOWER 78" RCVR 8 KHz R SIGNAL LD1R 0.001/ohm 0.001/ohm INP<br />
LD1X MMHO MMHO LOWER 78" RCVR 8 KHz X SIGNAL LD1X 0.001/ohm 0.001/ohm INP<br />
LD2R MMHO MMHO LOWER 69" RCVR 8 KHz R SIGNAL LD2R 0.001/ohm 0.001/ohm INP<br />
LU5R MMHO MMHO UPPER 30" RCVR 8 KHz R SIGNAL LU5R 0.001/ohm 0.001/ohm INP<br />
HU4X MMHO MMHO UPPER 42" RCVR 32KHz X SIGNAL HU4X 0.001/ohm 0.001/ohm INP<br />
HT60 OHMM OHMM HRI DEEP RES. 2FT RES 60INCH I HT60 ohm.m ohm.m RES<br />
LU4R MMHO MMHO UPPER 42" RCVR 8 KHz R SIGNAL LU4R 0.001/ohm 0.001/ohm INP<br />
VRES IN IN HRI VERTICAL RESOLUTION VRES IN IN RES<br />
VRES FT FT RESOLUTION OF VAR CURVES VRES ft ft RES<br />
XFRA HRI DEEP X FRACTION XFRAC RES<br />
XHRF XMTR REF 32KHz X DELAYED XHRF INP<br />
ZB DFL BUCK Z ZB RES<br />
STEM DEGF DEGC HRI SONDE TEMPERATURE STEM degF degC RES<br />
HT90 OHMM OHMM HRI DEEP RES. 2FT RES 90INCH I HT90 ohm.m ohm.m RES<br />
SP MV MV ANALOG SPONTANEOUS POTENTIAL SP mV mV INP<br />
HT40 OHMM OHMM HRI DEEP RES. 2FT RES 40INCH I HT40 ohm.m ohm.m RES<br />
HT30 OHMM OHMM HRI DEEP RES. 2FT RES 30INCH I HT30 ohm.m ohm.m RES<br />
HT24 OHMM OHMM HRI DEEP RES. 2FT RES 24INCH I HT24 ohm.m ohm.m RES<br />
HT09 OHMM OHMM HRAI 90 IN RAD RESIST 2FT HT09 ohm.m ohm.m RES<br />
HT03 OHMM OHMM HRAI 30 IN RAD RESIST 2FT HT03 ohm.m ohm.m RES<br />
HT02 OHMM OHMM HRAI 20 IN RAD RESIST 2FT HT02 ohm.m ohm.m RES<br />
HU1R MMHO MMHO UPPER 78" RCVR 32KHz R SIGNAL HU1R 0.001/ohm 0.001/ohm INP<br />
RMUD OHMM OHMM MUD RESISTIVITY RMUD ohm.m ohm.m RES<br />
9-18 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
HT01 OHMM OHMM HRAI 10 IN RAD RESIST 2FT HT01 ohm.m ohm.m RES<br />
LU5X MMHO MMHO UPPER 30" RCVR 8 KHz X SIGNAL LU5X 0.001/ohm 0.001/ohm INP<br />
MQCA MMHO MMHO HRI MEDIUM QUALITY CAL MQCAL 0.001/ohm 0.001/ohm INP<br />
MQZE MMHO MMHO HRI MEDIUM QUALITY ZERO MQZER 0.001/ohm 0.001/ohm INP<br />
MRCO MMHO MMHO HRI MEDIUM R CORRECTION MRCO 0.001/ohm 0.001/ohm RES<br />
MXCO MMHO MMHO HRI MEDIUM X CORRECTION MXCO 0.001/ohm 0.001/ohm RES<br />
TMPF DEGF DEGC FEEDPIPE TEMP CALCULATED TMPF degF degC RES<br />
RMAN RIGHT MANDREL RMAN RES<br />
LU4X MMHO MMHO UPPER 42" RCVR 8 KHz X SIGNAL LU4X 0.001/ohm 0.001/ohm INP<br />
RSO RIGHT STANDOFF RSO RES<br />
RT OHMM OHMM UNINVADED ZONE RESISTIVITY RT ohm.m ohm.m RES<br />
RX0 OHMM OHMM INVADED ZONE RESISTIVITY RX0 ohm.m ohm.m RES<br />
RXRT RXO OVER RT RXRT RES<br />
RXRT RXO OVER RT RXRT RES<br />
SP MV MV SPONTANEOUS POTENTIAL SP mV mV RES<br />
RHRF XMTR REF 32KHz R DELAYED RHRF INP<br />
DBH2 MMHO MMHO BOREHOLE CORRECTIONS D3 DBH2 0.001/ohm 0.001/ohm RES<br />
DDRY HRI DECONVOLED DEEP RY DDRY RES<br />
CT03 MMHO MMHO HRAI 30 IN RADIAL COND 2FT CT03 0.001/ohm 0.001/ohm RES<br />
CT06 MMHO MMHO HRAI 60 IN RADIAL COND 2FT CT06 0.001/ohm 0.001/ohm RES<br />
CT09 MMHO MMHO HRAI 90 IN RADIAL COND 2FT CT09 0.001/ohm 0.001/ohm RES<br />
CT12 MMHO MMHO HRAI 120 IN RADIAL COND 2FT CT12 0.001/ohm 0.001/ohm RES<br />
D1 IN MM INNER RADIAL DEPTH OF INVASION D1 in mm RES<br />
D2 IN IN OUTTER RADIAL DPTH OF INVASION D2 in IN RES<br />
CT01 MMHO MMHO HRAI 10 IN RADIAL COND 2FT CT01 0.001/ohm 0.001/ohm RES<br />
DBH1 MMHO MMHO BOREHOLE CORRECTIONS D2 DBH1 0.001/ohm 0.001/ohm RES<br />
CO12 MMHO MMHO HRAI 120 IN RADIAL COND 1FT CO12 0.001/ohm 0.001/ohm RES<br />
DBH3 MMHO MMHO BOREHOLE CORRECTIONS D4 DBH3 0.001/ohm 0.001/ohm RES<br />
DBH4 MMHO MMHO BOREHOLE CORRECTIONS U5 DBH4 0.001/ohm 0.001/ohm RES<br />
DBH5 MMHO MMHO BOREHOLE CORRECTIONS D6 DBH5 0.001/ohm 0.001/ohm RES<br />
DBH6 MMHO MMHO BOREHOLE CORRECTIONS U4 DBH6 0.001/ohm 0.001/ohm RES<br />
DBH7 MMHO MMHO BOREHOLE CORRECTIONS U3 DBH7 0.001/ohm 0.001/ohm RES<br />
DBH8 MMHO MMHO BOREHOLE CORRECTIONS U2 DBH8 0.001/ohm 0.001/ohm RES<br />
Mnemonics 9-19<br />
Type_<br />
Data
Serv_Name<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
DBH9 MMHO MMHO BOREHOLE CORRECTIONS U1 DBH9 0.001/ohm 0.001/ohm RES<br />
HD6X MMHO MMHO LOWER 18" RCVR 32KHz X SIGNAL HD6X 0.001/ohm 0.001/ohm INP<br />
DBH0 MMHO MMHO BOREHOLE CORRECTIONS D1 DBH0 0.001/ohm 0.001/ohm RES<br />
CF06 MMHO MMHO HRAI 60 IN RADIAL COND 4FT CF06 0.001/ohm 0.001/ohm RES<br />
BH30 MMHO MMHO BOREHOLE CORRECTIONS 30" BH30 0.001/ohm 0.001/ohm RES<br />
BH42 MMHO MMHO BOREHOLE CORRECTIONS 42" BH42 0.001/ohm 0.001/ohm RES<br />
BH54 MMHO MMHO BOREHOLE CORRECTIONS 54" BH54 0.001/ohm 0.001/ohm RES<br />
BH69 MMHO MMHO BOREHOLE CORRECTIONS 69" BH69 0.001/ohm 0.001/ohm RES<br />
BH78 MMHO MMHO BOREHOLE CORRECTIONS 78" BH78 0.001/ohm 0.001/ohm RES<br />
CALC IN IN CALC DIAMETER CALC in IN RES<br />
CF01 MMHO MMHO HRAI 10 IN RADIAL COND 4FT CF01 0.001/ohm 0.001/ohm RES<br />
CT02 MMHO MMHO HRAI 20 IN RADIAL COND 2FT CT02 0.001/ohm 0.001/ohm RES<br />
CF03 MMHO MMHO HRAI 30 IN RADIAL COND 4FT CF03 0.001/ohm 0.001/ohm RES<br />
DDX HRI DECONVOLED DEEP X DDX RES<br />
CF09 MMHO MMHO HRAI 90 IN RADIAL COND 4FT CF09 0.001/ohm 0.001/ohm RES<br />
CF12 MMHO MMHO HRAI 120 IN RADIAL COND 4FT CF12 0.001/ohm 0.001/ohm RES<br />
CO01 MMHO MMHO HRAI 10 IN RADIAL COND 1FT CO01 0.001/ohm 0.001/ohm RES<br />
CO01 MMHO MMHO HRAI 10 IN RADIAL COND 1FT CO01 0.001/ohm 0.001/ohm RES<br />
CO02 MMHO MMHO HRAI 20 IN RADIAL COND 1FT CO02 0.001/ohm 0.001/ohm RES<br />
CO03 MMHO MMHO HRAI 30 IN RADIAL COND 1FT CO03 0.001/ohm 0.001/ohm RES<br />
CO06 MMHO MMHO HRAI 60 IN RADIAL COND 1FT CO06 0.001/ohm 0.001/ohm RES<br />
CO09 MMHO MMHO HRAI 90 IN RADIAL COND 1FT CO09 0.001/ohm 0.001/ohm RES<br />
CF02 MMHO MMHO HRAI 20 IN RADIAL COND 4FT CF02 0.001/ohm 0.001/ohm RES<br />
DO69 OHMM OHMM AVG DECON 69" 1FT DO69 ohm.m ohm.m RES<br />
DDRX HRI DECONVOLED DEEP RX DDRX RES<br />
DLS4 OHMM OHMM SYMMETRIZED 8K S42" DLS4 ohm.m ohm.m RES<br />
DLU5 OHMM OHMM VERT DECON 8K UPPER 30" DLU5 ohm.m ohm.m RES<br />
DMR HRI DECONVOLED MEDIUM R DMR RES<br />
DMY HRI DECONVOLED MEDIUM Y DMY RES<br />
DO18 OHMM OHMM AVG DECON 18" 1FT DO18 ohm.m ohm.m RES<br />
DO30 OHMM OHMM AVG DECON 30" 1FT DO30 ohm.m ohm.m RES<br />
DLS2 OHMM OHMM SYMMETRIZED 8K S69" DLS2 ohm.m ohm.m RES<br />
DO54 OHMM OHMM AVG DECON 54" 1FT DO54 ohm.m ohm.m RES<br />
9-20 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
HRAI/HRI - HIGH RES ARRAY<br />
IND<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
DLS1 OHMM OHMM SYMMETRIZED 8K S78" DLS1 ohm.m ohm.m RES<br />
DO78 OHMM OHMM AVG DECON 78" 1FT DO78 ohm.m ohm.m RES<br />
DQCA HRI DEEP QUALITY CAL DQCAL INP<br />
DQU0 MMHO MMHO QUALITY D1 DQU0 0.001/ohm 0.001/ohm RES<br />
DQU1 MMHO MMHO QUALITY D2 DQU1 0.001/ohm 0.001/ohm RES<br />
DQU2 MMHO MMHO QUALITY D3 DQU2 0.001/ohm 0.001/ohm RES<br />
DQU3 MMHO MMHO QUALITY D4 DQU3 0.001/ohm 0.001/ohm RES<br />
DQU4 MMHO MMHO QUALITY U5 DQU4 0.001/ohm 0.001/ohm RES<br />
DQU5 MMHO MMHO QUALITY D6 DQU5 0.001/ohm 0.001/ohm RES<br />
DO42 OHMM OHMM AVG DECON 42" 1FT DO42 ohm.m ohm.m RES<br />
DFLF OHMM OHMM DIGITALLY FOCUSED LATEROLOG FL DFLF ohm.m ohm.m RES<br />
DDY HRI DECONVOLED DEEP Y DDY RES<br />
DF18 OHMM OHMM AVG DECON 18" 4FT DF18 ohm.m ohm.m RES<br />
DF30 OHMM OHMM AVG DECON 30" 4FT DF30 ohm.m ohm.m RES<br />
DF42 OHMM OHMM AVG DECON 42" 4FT DF42 ohm.m ohm.m RES<br />
DF54 OHMM OHMM AVG DECON 54" 4FT DF54 ohm.m ohm.m RES<br />
DF69 OHMM OHMM AVG DECON 69" 4FT DF69 ohm.m ohm.m RES<br />
DQU6 MMHO MMHO QUALITY U4 DQU6 0.001/ohm 0.001/ohm RES<br />
DLS3 OHMM OHMM SYMMETRIZED 8K S54" DLS3 ohm.m ohm.m RES<br />
DFL OHMM OHMM DIGITALLY FOCUSED LATEROLOG DFL ohm.m ohm.m RES<br />
BH18 MMHO MMHO BOREHOLE CORRECTIONS 18" BH18 0.001/ohm 0.001/ohm RES<br />
DHD6 OHMM OHMM VERT DECON 32K LOWER 18" DHD6 ohm.m ohm.m RES<br />
DHS1 OHMM OHMM SYMMETRIZED 32K S78" DHS1 ohm.m ohm.m RES<br />
DHS2 OHMM OHMM SYMMETRIZED 32K S69" DHS2 ohm.m ohm.m RES<br />
DHS3 OHMM OHMM SYMMETRIZED 32K S54" DHS3 ohm.m ohm.m RES<br />
DHS4 OHMM OHMM SYMMETRIZED 32K S42" DHS4 ohm.m ohm.m RES<br />
DHU5 OHMM OHMM VERT DECON 32K UPPER 30" DHU5 ohm.m ohm.m RES<br />
DI IN IN RADIAL DEPTH OF INVASION DI IN IN RES<br />
DLD6 OHMM OHMM VERT DECON 8K LOWER 18" DLD6 ohm.m ohm.m RES<br />
DF78 OHMM OHMM AVG DECON 78" 4FT DF78 ohm.m ohm.m RES<br />
HSN - SHORT NORMAL RES SGRU OHMM OHMM UNFILTERED NORMAL RESISTIVITY SGRU ohm.m ohm.m RES<br />
HSN - SHORT NORMAL RES SGRD OHMM OHMM SHORT NORMAL RESISTIVITY SGRD ohm.m ohm.m RES<br />
HSN - SHORT NORMAL RES RXRT RXO OVER RT RXRT RES<br />
ICT - SIX INDEP ARM CALIPER SO1 IN MM STAND OFF ARM 1 STAND1 in mm RES<br />
Mnemonics 9-21<br />
Type_<br />
Data
Serv_Name<br />
ICT - SIX INDEP ARM CALIPER RAD6 IN MM RADIUS CALIPER ARM # 6 RAD6 in mm RES<br />
ICT - SIX INDEP ARM CALIPER RAD5 IN MM RADIUS CALIPER ARM # 5 RAD5 in mm RES<br />
ICT - SIX INDEP ARM CALIPER RAD4 IN MM RADIUS CALIPER ARM # 4 RAD4 in mm RES<br />
ICT - SIX INDEP ARM CALIPER RAD3 IN MM RADIUS CALIPER ARM # 3 RAD3 in mm RES<br />
ICT - SIX INDEP ARM CALIPER RAD2 IN MM RADIUS CALIPER ARM # 2 RAD2 in mm RES<br />
ICT - SIX INDEP ARM CALIPER RAD1 IN MM RADIUS CALIPER ARM # 1 RAD1 in mm RES<br />
ICT - SIX INDEP ARM CALIPER SO6 IN MM STAND OFF ARM 6 STAND6 in mm RES<br />
ICT - SIX INDEP ARM CALIPER SO5 IN MM STAND OFF ARM 5 STAND5 in mm RES<br />
ICT - SIX INDEP ARM CALIPER SO4 IN MM STAND OFF ARM 4 STAND4 in mm RES<br />
ICT - SIX INDEP ARM CALIPER HAZI DEG DEG DRIFT AZIMUTH HAZI deg deg RES<br />
ICT - SIX INDEP ARM CALIPER SO2 IN MM STAND OFF ARM 2 STAND2 in mm RES<br />
ICT - SIX INDEP ARM CALIPER CAL6 IN MM ICT CALIPER ARM #6 CAL6 in mm RES<br />
ICT - SIX INDEP ARM CALIPER CALA IN MM ICT AVERAGE CALIPER CALA in mm RES<br />
ICT - SIX INDEP ARM CALIPER CAL5 IN MM ICT CALIPER ARM #5 CAL5 in mm RES<br />
ICT - SIX INDEP ARM CALIPER CAL3 IN MM ICT CALIPER ARM #3 CAL3 in mm RES<br />
ICT - SIX INDEP ARM CALIPER CAL2 IN MM ICT CALIPER ARM #2 CAL2 in mm RES<br />
ICT - SIX INDEP ARM CALIPER CAL1 IN MM ICT CALIPER ARM #1 CAL1 in mm RES<br />
ICT - SIX INDEP ARM CALIPER C36 IN MM ICT CALIPER PAIR 3-6 C36 in mm RES<br />
ICT - SIX INDEP ARM CALIPER C25 IN MM ICT CALIPER PAIR 2-5 C25 in mm RES<br />
ICT - SIX INDEP ARM CALIPER C14 IN MM ICT CALIPER PAIR 1-4 C14 in mm RES<br />
ICT - SIX INDEP ARM CALIPER SO3 IN MM STAND OFF ARM 3 STAND3 in mm RES<br />
ICT - SIX INDEP ARM CALIPER CAL4 IN MM ICT CALIPER ARM #4 CAL4 in mm RES<br />
ICT - SIX INDEP ARM CALIPER HAZI DEG DEG DRIFT AZIMUTH HAZI deg deg RES<br />
ICT - SIX INDEP ARM CALIPER DEVI DEG DEG DRIFT ANGLE DEVI deg deg RES<br />
ICT - SIX INDEP ARM CALIPER DEVI DEG DEG DRIFT ANGLE DEVI deg deg RES<br />
ICT - SIX INDEP ARM CALIPER DCAL IN MM DIFFERENTIAL CLAIPER DCAL in mm RES<br />
ICT - SIX INDEP ARM CALIPER HDIA IN MM MEASURED HOLE DIAMETER HDIA in mm RES<br />
ICT - SIX INDEP ARM CALIPER RB DEG DEG RELEATIVE BEARNING RB deg deg RES<br />
ICT - SIX INDEP ARM CALIPER PRES CALIPER PAD FORCE PRES RES<br />
ICT - SIX INDEP ARM CALIPER DMIN IN MM MINIMUM CALIPER PAIR DMIN in mm RES<br />
ICT - SIX INDEP ARM CALIPER DMAX IN MM MAXIMUM CALIPER PAIR DMAX in mm RES<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
RB DEG DEG RELATIVE BEARING RB deg deg RES<br />
MAGD MAGNETIC DIP FOR DIRECT TOOL MAGD RES<br />
MAGZ MAGNETOMETER Z-AXIS MAGZ RES<br />
MAGY MAGNETOMETER Y-AXIS MAGY RES<br />
MAGX MAGNETOMETER X-AXIS MAGX RES<br />
TLFC TOOL FACE DIRECTION TLFC RES<br />
GTOT TOAL GRAVITY FIELD - NAV TOOL GTOT RES<br />
BTOT TOAL MAGNETIC FIELD - NAV TOOL BTOT RES<br />
AZI1 DEG DEG PAD 1 AZIMUTH AZI1 deg deg RES<br />
ACCZ G G ACCELEROMETER Z-AXIS ACCZ G G RES<br />
ACCQ G G ACCELEROMETER QUALITY ACCQ G G RES<br />
ACCX G G ACCELEROMETER X-AXIS ACCX G G RES<br />
9-22 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
IDT - INSITE DIRECTIONAL<br />
TOOL<br />
MTMP MAGNET TEMPERATURE MTMP RES<br />
ACCY G G ACCELEROMETER Y-AXIS ACCY G G RES<br />
MAGQ CALCULATED MAGNETIC FIELD MAGQ RES<br />
MACT - MULTI-ARM CALIPER CALA IN MM AVERAGE CALIPER CALA in mm RES<br />
MACT - MULTI-ARM CALIPER MXID IN MM CASING MAXIMUM ID MXID in mm RES<br />
MACT - MULTI-ARM CALIPER MNID IN MM CASING MINIMUM ID MNID in mm RES<br />
MACT - MULTI-ARM CALIPER RMWL IN MM REMAINING WALL THICKNESS RMWL in mm RES<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
PC3 PU PU Bin Sums 1-3 for display PC3 pu pu RES<br />
PC2 PU PU Bin Sums 1-2 for display PC2 pu pu RES<br />
PC4 PU PU Bin Sums 1-4 for display PC4 pu pu RES<br />
PC5 PU PU Bin Sums 1-5 for display PC5 pu pu RES<br />
PC1 PU PU Bin Sums 1-1 for display PC1 pu pu RES<br />
P9 PU PU BIN 9 Porosity P9 pu pu INP<br />
P7 PU PU BIN 7 Porosity P7 pu pu INP<br />
P6 PU PU BIN 6 Porosity P6 pu pu INP<br />
TPW TOTAL POROSITY Distribution TPW RES<br />
P5 PU PU BIN 5 Porosity P5 pu pu INP<br />
PC6 PU PU Bin Sums 1-6 for display PC6 pu pu RES<br />
SEQN Sequence Number SEQN INP<br />
P8 PU PU BIN 8 Porosity P8 pu pu INP<br />
PC7 PU PU Bin Sums 1-7 for display PC7 pu pu RES<br />
PC8 PU PU Bin Sums 1-8 for display PC8 pu pu RES<br />
PC9 PU PU Bin Sums 1-9 for display PC9 pu pu RES<br />
PC10 PU PU Bin Sums 1-10 for display PC10 pu pu RES<br />
PC11 PU PU Bin Sums 1-11 for display PC11 pu pu RES<br />
PC12 PU PU Bin Sums 1-12 for display PC12 pu pu RES<br />
PC13 PU PU Bin Sums 1-13 for display PC13 pu pu RES<br />
WTME MRIL WAIT TIEM WTME INP<br />
PERM Computed Permiability PERM INP<br />
RDSP Raw Echos for Display RDSP INP<br />
STAT DATA STATUS STAT INP<br />
T2W MSEC MSEC T2 Distribution Waveform T2W MSEC MSEC RES<br />
TPHI DECP DECP MRIL FULL POROSITY TPHI 100 pu 100 pu RES<br />
PHA Corrected Echo Phases PHAS INP<br />
Mnemonics 9-23<br />
Type_<br />
Data
Serv_Name<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
MRIL - MAGNETIC RESONANCE<br />
IMAGE<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
FRQ3 MRIL FREQUENCY 3 FRQ3 INP<br />
P4 PU PU BIN 4 Porosity P4 pu pu INP<br />
FRQ4 MRIL FREQUENCY 4 FRQ4 INP<br />
ACTN MRIL ACTIVATION NAME ACTN INP<br />
TE MRIL ECHO SPACING TE INP<br />
FRQ2 MRIL FREQUENCY 2 FRQ2 INP<br />
FRQ1 MRIL FREQUENCY 1 FRQ1 INP<br />
FRQ0 MRIL FREQUENCY 0 FRQ0 INP<br />
ANT DEG DEG ANTENNA TEMPERATURE ANT deg deg INP<br />
B1 MG MG B1 SENSOR B1 MG MG INP<br />
B1MD MG MG B1 ADJUSTED for TEMPERATURE B1MOD MG MG INP<br />
CHI CHI from analysis CHI INP<br />
DIH DIAM of INVESTIGATION HYDROGEN DIH RES<br />
ECHO Corrected Echo Amplitudes ECHO INP<br />
GAIN MRIL GAIN GAIN INP<br />
MBVI PU PU MRIL Bound Volume MBVI pu pu INP<br />
MDPT DATA DEPTH MDPT INP<br />
MPHI PU PU MRIL EFFECTIVE POROSITY MPHI pu pu INP<br />
P1 PU PU BIN 1 Porosity P1 pu pu INP<br />
P10 PU PU BIN 10 Porosity P10 pu pu INP<br />
P11 PU PU BIN 11 Porosity P11 pu pu INP<br />
P3 PU PU BIN 3 Porosity P3 pu pu INP<br />
P12 PU PU BIN 12 Porosity P12 pu pu INP<br />
P2 PU PU BIN 2 Porosity P2 pu pu INP<br />
P13 PU PU BIN 13 Porosity P13 pu pu INP<br />
DIS DIAM of INVESTIGATION SODIUM DIS RES<br />
MSFL/ML - MICRO RES MNOR OHMM OHMM MICROLOG NORMAL MNOR ohm.m ohm.m RES<br />
MSFL/ML - MICRO RES MSFL OHMM OHMM MSFL (FRXO) MSFL ohm.m ohm.m RES<br />
MSFL/ML - MICRO RES RXRT RXO OVER RT RXRT RES<br />
MSFL/ML - MICRO RES MSFU OHMM OHMM MSFL UNFILTERED MSFLUF ohm.m ohm.m RES<br />
MSFL/ML - MICRO RES MINV OHMM OHMM MICROLOG LATERAL (INVERSE) MINV ohm.m ohm.m RES<br />
PL TOOLS - PRODUCTION FCCW RPS RPS FLOW (CONTINUOUS) CW FCCW RPS RPS RES<br />
PL TOOLS - PRODUCTION DPRS PSI KPA DIFFERENTIAL PRESSURE DPRS psi Kpa RES<br />
PL TOOLS - PRODUCTION DPRS PSI KPA DIFFERENTIAL PRESSURE DPRS psi Kpa RES<br />
PL TOOLS - PRODUCTION DTEM DEGF DEGC DIFFERENTIAL TEMPERATURE DTEM degF degC RES<br />
PL TOOLS - PRODUCTION DTEM DEGF DEGC DIFFERENTIAL TEMPERATURE DTMP degF degC RES<br />
9-24 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
PL TOOLS - PRODUCTION FBCC RPS RPS FLOW (FULL BORE) CCW FBCC RPS RPS RES<br />
PL TOOLS - PRODUCTION FCCC RPS RPS FLOW (CONTINUOUS) CCW FCCC RPS RPS RES<br />
PL TOOLS - PRODUCTION FCON RPS RPS AVERAGE FLOW (CONTINUOUS) FCON RPS RPS RES<br />
PL TOOLS - PRODUCTION FDC CPS CPS FLUID DENSITY COUNTS FDC 1.0/S 1.0/S RES<br />
PL TOOLS - PRODUCTION FDDP DIFFERENTIAL PRESSURE FDDP RES<br />
PL TOOLS - PRODUCTION FDEN G/CC K/M3 FLUID DENSITY FDEN G/CC Kg/m3 RES<br />
PL TOOLS - PRODUCTION FICC RPS RPS FLOW (INLINE) CCW FICC RPS RPS RES<br />
PL TOOLS - PRODUCTION FINL RPS RPS AVERAGE FLOW (INLINE) FLOWI RPS RPS RES<br />
PL TOOLS - PRODUCTION FICW RPS RPS FLOW (INLINE) CW FICW RPS RPS RES<br />
PL TOOLS - PRODUCTION FBCW RPS RPS FLOW (FULL BORE) CW FBCW RPS RPS RES<br />
PL TOOLS - PRODUCTION CP4 INDEX INDEX SENSOR 4 CAPACITANCE INDEX CP4 INDEX INDEX RES<br />
PL TOOLS - PRODUCTION CALX SQIN CROSS SECTION AREA CALX SQIN RES<br />
PL TOOLS - PRODUCTION CHMA HORIZONTAL IMAGE MAP CHMAP RES<br />
PL TOOLS - PRODUCTION TEMP DEGF DEGC TEMPERATURE TEMP degF degC RES<br />
PL TOOLS - PRODUCTION CP1 SENSOR 1 CAPACITANCE INDEX CP1 RES<br />
PL TOOLS - PRODUCTION FLFB RPS RPS AVERAGE FLOW (FULL BORE) FLOWFB RPS RPS RES<br />
PL TOOLS - PRODUCTION CP11 INDEX INDEX SENSOR 11 CAPACITANCE INDEX CP11 INDEX INDEX RES<br />
PL TOOLS - PRODUCTION CP12 INDEX INDEX SENSOR 12 CAPACITANCE INDEX CP12 INDEX INDEX RES<br />
PL TOOLS - PRODUCTION CP10 INDEX INDEX SENSOR 10 CAPACITANCE INDEX CP10 INDEX INDEX RES<br />
PL TOOLS - PRODUCTION CP3 INDEX INDEX SENSOR 3 CAPACITANCE INDEX CP3 INDEX INDEX RES<br />
PL TOOLS - PRODUCTION DIMV MV MV DIFFERENTIAL MILLIVOLTS DIFFMV mV mV RES<br />
PL TOOLS - PRODUCTION CP5 SENSOR 5 CAPACITANCE INDEX CP5 RES<br />
PL TOOLS - PRODUCTION CP6 INDEX INDEX SENSOR 6 CAPACITANCE INDEX CP6 INDEX INDEX RES<br />
PL TOOLS - PRODUCTION CP7 INDEX INDEX SENSOR 7 CAPACITANCE INDEX CP7 INDEX INDEX RES<br />
PL TOOLS - PRODUCTION CP8 INDEX INDEX SENSOR 8 CAPACITANCE INDEX CP8 INDEX INDEX RES<br />
PL TOOLS - PRODUCTION CP9 INDEX INDEX SENSOR 9 CAPACITANCE INDEX CP9 INDEX INDEX RES<br />
PL TOOLS - PRODUCTION CRMA RADIAL IMAGE MAP CRMAP RES<br />
PL TOOLS - PRODUCTION CSDL F/M M/M CABLE SPEED - DELAYED CSDL ft/m m/min INP<br />
PL TOOLS - PRODUCTION CP2 INDEX INDEX SENSOR 2 CAPACITANCE INDEX CP2 INDEX INDEX RES<br />
PL TOOLS - PRODUCTION YTWA TURB TURB WATER HOLDUP - TURBULENT FLOW YTWAT TURB TURB RES<br />
PL TOOLS - PRODUCTION RHOG GM/CC KG/M3 GAS DENSITY RHOG GM/CC KG/M3 RES<br />
PL TOOLS - PRODUCTION YGHT % % GAS HOLDUP YGHT % % RES<br />
PL TOOLS - PRODUCTION YGHU % % GAS HOLDUP - UNLIMITED YGHU % % RES<br />
PL TOOLS - PRODUCTION YGHZ % % GAS HOLDUP - PVT UNCORRECTED YGHZ % % RES<br />
PL TOOLS - PRODUCTION YOD % % OIL HOLDUP FDR TOOL YOD % % RES<br />
PL TOOLS - PRODUCTION YGAS GAS HOLDUP YGAS RES<br />
PL TOOLS - PRODUCTION YOIL OIL HOLDUP YOIL RES<br />
PL TOOLS - PRODUCTION TEMP DEGF DEGC TEMPERATURE TEMP degF degC RES<br />
PL TOOLS - PRODUCTION YWAT WATER HOLDUP YWAT RES<br />
PL TOOLS - PRODUCTION YWAT LAMNR LAMNR WATER HOLDUP - LAMINAR FLOW YWAT LAMNR LAMNR RES<br />
PL TOOLS - PRODUCTION YWD % % WATER HOLDUP FDR TOOL YWD % % RES<br />
PL TOOLS - PRODUCTION YWH % % WATER HOLDUP YWH % % RES<br />
PL TOOLS - PRODUCTION CAL1 INCH CALIPER ARM 1 CAL1 in RES<br />
PL TOOLS - PRODUCTION CAL2 INCH CALIPER ARM 2 CAL2 in RES<br />
PL TOOLS - PRODUCTION YOH % % OIL HOLDUP YOH % % RES<br />
PL TOOLS - PRODUCTION HYDR CPS CPS CENTER SAMPLE HYDROMETER CPS HYDR 1.0/S 1.0/S RES<br />
PL TOOLS - PRODUCTION FTMP FDD SENSOR TEMPERATURE FTMP RES<br />
PL TOOLS - PRODUCTION GHCC CPS CPS GHT DEAD TIME & DECAY CORR CPS GHTCC 1.0/S 1.0/S RES<br />
PL TOOLS - PRODUCTION GHTC CPS CPS GHT DEAD TIME ONLY CORR CPS GHTC 1.0/S 1.0/S RES<br />
Mnemonics 9-25<br />
Type_<br />
Data
Serv_Name<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
PL TOOLS - PRODUCTION GR API API GAMMA RAY GR gAPI gAPI RES<br />
PL TOOLS - PRODUCTION GRCO API API GAMMA RAY CORRECTED GRCO gAPI gAPI RES<br />
PL TOOLS - PRODUCTION YGD % % GAS HOLDUP FDR TOOL YGD % % RES<br />
PL TOOLS - PRODUCTION GRS API API GAMMA RAY (SONDEX) GRS gAPI gAPI RES<br />
PL TOOLS - PRODUCTION FREF FREQUENCY REFERENCE FREF TEL<br />
PL TOOLS - PRODUCTION IDER ID OUT OF TOLERANCE WARNING IDWARN RES<br />
PL TOOLS - PRODUCTION ITMP F C INTERNAL TEMPERATURE INTMP ft C RES<br />
PL TOOLS - PRODUCTION PRBU PSI KG/M3 PRESSURE BUILDUP PRBU psi KG/M3 RES<br />
PL TOOLS - PRODUCTION PRES PSI KPA PRESSURE PRES psi Kpa RES<br />
PL TOOLS - PRODUCTION PRES PSIA KPA ABSOLUTE PRESSURE PRES PSIA Kpa RES<br />
PL TOOLS - PRODUCTION SIT DEGF DEGC SENSOR TEMPERATURE SIT degF degC RES<br />
PL TOOLS - PRODUCTION TEMP INTERNAL TEMPERATURE TEMP INP<br />
PL TOOLS - PRODUCTION GRCS API API GAMMA RAY CORRECTED (SONDEX) GRCS gAPI gAPI RES<br />
PSGT - PULSE SPECT GAMMA STUN CO STATISTICAL UNCERTAINTY STUN RES<br />
PSGT - PULSE SPECT GAMMA YCA CALCIUM YIELD CAPTURE YCA RES<br />
PSGT - PULSE SPECT GAMMA SPC2 PSGT CAPTURE 2 SPECTRUM SPC2 INP<br />
PSGT - PULSE SPECT GAMMA SPBK PSGT BACKGROUND SPECTRUM SPBK INP<br />
PSGT - PULSE SPECT GAMMA SPC1 PSGT CAPTURE 1 SPECTRUM SPC1 INP<br />
PSGT - PULSE SPECT GAMMA SPEN PSGT INELASTIC SPECTRUM SPEN INP<br />
PSGT - PULSE SPECT GAMMA SWPO PSGT TOOL MODE SWPOS INP<br />
PSGT - PULSE SPECT GAMMA TCCR TOTAL COUNTS CAPTURE TCCR RES<br />
PSGT - PULSE SPECT GAMMA TMD1 TMD GATE 1 UNFILTERED TMD1 RES<br />
PSGT - PULSE SPECT GAMMA TMD2 TMD GATE 2 UNFILTERED TMD2 RES<br />
PSGT - PULSE SPECT GAMMA TMD3 TMD GATE 3 UNFILTERED TMD3 RES<br />
PSGT - PULSE SPECT GAMMA TMD4 TMD GATE 4 UNFILTERED TMD4 RES<br />
PSGT - PULSE SPECT GAMMA TMD5 TMD GATE 5 UNFILTERED TMD5 RES<br />
PSGT - PULSE SPECT GAMMA SIC SULPHUR INDICATOR_C SIC RES<br />
PSGT - PULSE SPECT GAMMA TMDS CU CU TMD SIGMA TMDS cu CU RES<br />
PSGT - PULSE SPECT GAMMA SIAI SILICON_ACT_INDICATOR SIAI SIAI RES<br />
PSGT - PULSE SPECT GAMMA YCL CHLORINE YIELD CAPTURE YCL RES<br />
PSGT - PULSE SPECT GAMMA YFE IRON YIELD CAPTURE YFE RES<br />
PSGT - PULSE SPECT GAMMA YH HYDROGEN YIELD CAPTURE YH RES<br />
PSGT - PULSE SPECT GAMMA YIC CARBON YIELD INELASTIC YIC RES<br />
PSGT - PULSE SPECT GAMMA YICA CALCIUM YIELD INELASTIC YICA RES<br />
PSGT - PULSE SPECT GAMMA YIO OXYGEN YIELD CAPTURE YIO RES<br />
PSGT - PULSE SPECT GAMMA YISI SILICON YIELD INELASTIC YISI RES<br />
PSGT - PULSE SPECT GAMMA YK POTASSIUM YIELD CAPTURE YK RES<br />
PSGT - PULSE SPECT GAMMA YS SULPHUR YIELD CAPTURE YS RES<br />
PSGT - PULSE SPECT GAMMA YSI SILICON YIELD CAPTURE YSI RES<br />
PSGT - PULSE SPECT GAMMA YTI TITANIUM YIELD CAPTURE YTI RES<br />
PSGT - PULSE SPECT GAMMA ZOFF ZERO OFFSET PSGT.SHOP CAL S-2 ZOFF RES<br />
PSGT - PULSE SPECT GAMMA TMD6 TMD GATE 6 UNFILTERED TMD6 RES<br />
PSGT - PULSE SPECT GAMMA FTR SPECTRAL FIT ERROR FTR RES<br />
PSGT - PULSE SPECT GAMMA CLIC CHLORINE INDICATOR_C CLIC RES<br />
PSGT - PULSE SPECT GAMMA COIR INELASTIC CO RATIO COIR RES<br />
PSGT - PULSE SPECT GAMMA COYR CO YIELD RATIO INELASTIC COYR RES<br />
PSGT - PULSE SPECT GAMMA CRAT COMPTON RATIO (OAI/OBI) CRAT RES<br />
PSGT - PULSE SPECT GAMMA CTIM MSEC MSEC ACCUMULATION TIME MILLISECONDS C_TIME MSEC MSEC RES<br />
PSGT - PULSE SPECT GAMMA DTMP DETECTOR TEMPERATURE DTMP RES<br />
9-26 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
PSGT - PULSE SPECT GAMMA F110 % % PSGT 110 VOLT F110 % % RES<br />
PSGT - PULSE SPECT GAMMA F17V % % PSGT 17V LOAD F17V % % RES<br />
PSGT - PULSE SPECT GAMMA F2KV % % PSGT 2K VOLT LOAD F2KV % % RES<br />
PSGT - PULSE SPECT GAMMA F50V % % PSGT 50 V LOAD F50V % % RES<br />
PSGT - PULSE SPECT GAMMA FEIC IRON INDICATOR_C FEIC RES<br />
PSGT - PULSE SPECT GAMMA SIIC SILICON INDICATOR_C SIIC RES<br />
PSGT - PULSE SPECT GAMMA FREP % % PSGT REPLENISHER FREP % % RES<br />
PSGT - PULSE SPECT GAMMA LIRI INELASTIC LITHOLOGY INDEX LIRI RES<br />
PSGT - PULSE SPECT GAMMA RIC INELASTIC CAPTURE RATIO RIC RES<br />
PSGT - PULSE SPECT GAMMA PSST PSGT TOOL STATE PSGST INP<br />
PSGT - PULSE SPECT GAMMA PSPC PSGT DISPLAY SPECTRUM PSPC RES<br />
PSGT - PULSE SPECT GAMMA OBI OXYGEN BACKGROUND INDICATOR OBI RES<br />
PSGT - PULSE SPECT GAMMA FERC IRON RATIO CAPTURE FERC RES<br />
PSGT - PULSE SPECT GAMMA LIYR LITH YIELD RATIO INEL LIYR RES<br />
PSGT - PULSE SPECT GAMMA CAIC CALCIUM INDICATOR_C CAIC RES<br />
PSGT - PULSE SPECT GAMMA KIC POTASSIUM INDICATOR_C KIC RES<br />
PSGT - PULSE SPECT GAMMA ITCR INELASTIC TOTAL ITCR RES<br />
PSGT - PULSE SPECT GAMMA IDER PSGT ID ERROR IDERR INP<br />
PSGT - PULSE SPECT GAMMA HPLI CAPTURE HYDROGEN PEAK HPLI RES<br />
PSGT - PULSE SPECT GAMMA HIC HYDROGEN INDICATOR_C HIC RES<br />
PSGT - PULSE SPECT GAMMA GOUT GENERATOR OUTPUT GOUT RES<br />
PSGT - PULSE SPECT GAMMA OAI OXYGEN ACTIVATION INDICATOR OAI RES<br />
RDT - RESERVOIR DESC TOOL C11 CURVE 11 C11 INP<br />
RDT - RESERVOIR DESC TOOL P1TE DEGF DEGC PROBE 1 TEMPERATURE P1TEMP degF degC INP<br />
RDT - RESERVOIR DESC TOOL PTHO PSI KPA PRESSURE THOUSANDS PTHO psi Kpa RES<br />
RDT - RESERVOIR DESC TOOL PTEN PSI KPA PRESSURE TENS PTEN psi Kpa RES<br />
RDT - RESERVOIR DESC TOOL PRES PSI KPA TOTAL PRESSURE PRES psi Kpa RES<br />
RDT - RESERVOIR DESC TOOL PRAT CC/S CC/S FPS PUMP MEASURED RATE PRATE 0.1 L/S 0.1 L/S INP<br />
RDT - RESERVOIR DESC TOOL POTE DEGF DEGC FPS OUTLET TEMPERATURE OUTTMP degF degC INP<br />
RDT - RESERVOIR DESC TOOL PONE PSI KPA RDT PRESSURE ONES PONE psi Kpa RES<br />
RDT - RESERVOIR DESC TOOL PITE DEGF DEGC FPS INLET TEMPERATURE INTMP degF degC INP<br />
RDT - RESERVOIR DESC TOOL PHUN PSI KPA PRESSURE HUNDREDS PHUN psi Kpa RES<br />
RDT - RESERVOIR DESC TOOL PHST PSI KPA RDT HYDROSTATIC PRESSURE PHST psi Kpa RES<br />
RDT - RESERVOIR DESC TOOL PHFL PSI KPA RDT HYDRAULIC PRESSURE PHFL psi Kpa RES<br />
RDT - RESERVOIR DESC TOOL PHDS PSI KPA PRESSURE HUNDREDTHS PHDS psi Kpa RES<br />
RDT - RESERVOIR DESC TOOL HPRS PSI KPA FPS HYDRALIC PRESSURE SYPRES psi Kpa INP<br />
RDT - RESERVOIR DESC TOOL P2PS PSI PSI PROBE 2 PRESSURE P2PRES PSI PSI INP<br />
RDT - RESERVOIR DESC TOOL PTTE DEGF DEGC PRETEST TEMPERATURE PTTEMP degF degC INP<br />
RDT - RESERVOIR DESC TOOL P1PS PSI PSI PROBE 1 PRESSURE P1PRES PSI PSI INP<br />
RDT - RESERVOIR DESC TOOL OPTR CC/S CC/S FPS OPTIMUM PUMP RATE OPTR CC/S CC/S INP<br />
RDT - RESERVOIR DESC TOOL OPTR CC/S CC/S FPS OPTIMUM PUMP RATE OPTR CC/S CC/S INP<br />
RDT - RESERVOIR DESC TOOL OFFS OFFSET OFFSET TEL<br />
RDT - RESERVOIR DESC TOOL NOIS NOISE NOISE TEL<br />
RDT - RESERVOIR DESC TOOL MTEM DEGF DEGC MAGNET TEMPERATURE TEMP2 degF degC TEL<br />
RDT - RESERVOIR DESC TOOL MSPD RPM RPM Motor Speed MOTSPD RPM RPM INP<br />
RDT - RESERVOIR DESC TOOL MRAT CC/S CC/S PRETEST MEASURED RATE MRATE 0.1 L/S 0.1 L/S INP<br />
RDT - RESERVOIR DESC TOOL HTMP DEGF DEGC HPS HYDRAULIC TEMPERATURE HYTEMP degF degC INP<br />
RDT - RESERVOIR DESC TOOL HTMP HPS HYDRAULIC TEMPERATURE HYTEMP INP<br />
RDT - RESERVOIR DESC TOOL HSVA SOLENOID VALVE A HPSSVA TEL<br />
Mnemonics 9-27<br />
Type_<br />
Data
Serv_Name<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
RDT - RESERVOIR DESC TOOL HPRS PSI KPA HPS HYDRALIC PRESSURE HYPRES psi Kpa INP<br />
RDT - RESERVOIR DESC TOOL P2TE DEGF DEGC PROBE 2 TEMPERATURE P2TEMP degF degC INP<br />
RDT - RESERVOIR DESC TOOL SVB PPS Solenoid Valve B PPSSVB TEL<br />
RDT - RESERVOIR DESC TOOL RHOG GM/CC GM/CC GAS DENSITY - EST. RHOG gm/cc gm/cc INP<br />
RDT - RESERVOIR DESC TOOL C1 CURVE 1 C1 INP<br />
RDT - RESERVOIR DESC TOOL ANSO KV/KH KV/KH ANISOTROPY ANISO Kv/Kh Kv/Kh INP<br />
RDT - RESERVOIR DESC TOOL VISC VISCOCITY VISC INP<br />
RDT - RESERVOIR DESC TOOL V50 50 VOLT DC V50 TEL<br />
RDT - RESERVOIR DESC TOOL V30 30 VOLT DC V30 TEL<br />
RDT - RESERVOIR DESC TOOL V200 200 VOLT DC V200 TEL<br />
RDT - RESERVOIR DESC TOOL UTLV SURFACE UTILITY VOLTAGE UTLVLT TEL<br />
RDT - RESERVOIR DESC TOOL UTLC SURFACE UTILITY CURRENT UTLCUR TEL<br />
RDT - RESERVOIR DESC TOOL SVG PPS Solenoid Valve G PPSSVG TEL<br />
RDT - RESERVOIR DESC TOOL SVF PPS Solenoid Valve F PPSSVF TEL<br />
RDT - RESERVOIR DESC TOOL SVE PPS Solenoid Valve E PPSSVE TEL<br />
RDT - RESERVOIR DESC TOOL PTHS PSI KPA PRESSURE TENTHS PTHS psi Kpa RES<br />
RDT - RESERVOIR DESC TOOL SVC PPS Solenoid Valve C PPSSVC TEL<br />
RDT - RESERVOIR DESC TOOL PTPS PSI PSI PRETEST PRESSURE PTPRES PSI PSI INP<br />
RDT - RESERVOIR DESC TOOL SVA PPS Solenoid Valve A PPSSVA TEL<br />
RDT - RESERVOIR DESC TOOL SPIK ECHO SPIKING INDICATOR SPIKE INP<br />
RDT - RESERVOIR DESC TOOL SMOB SHPERICAL MOBILITY MPTHS INP<br />
RDT - RESERVOIR DESC TOOL SEQ SEQUENCE NUMBER SEQ TEL<br />
RDT - RESERVOIR DESC TOOL SDEP FT M SFT SET DEPTH SDEP ft m RES<br />
RDT - RESERVOIR DESC TOOL RING RINGING RING TEL<br />
RDT - RESERVOIR DESC TOOL RHOF GM/CC GM/CC FLUID DENSITY RHOF gm/cc gm/cc INP<br />
RDT - RESERVOIR DESC TOOL QTMP DEGF DEGC QUARTZ GAUGE TEMPERATURE QGTEMP degF degC INP<br />
RDT - RESERVOIR DESC TOOL PWRF HIGH POWER FACTOR PWRFAC TEL<br />
RDT - RESERVOIR DESC TOOL PVOL CC CC PRETEST VOLUME PTVOL 0.01 L 0.01 L INP<br />
RDT - RESERVOIR DESC TOOL PTTH PSI KPA PRESSURE TEN THOUSANDS PTTH psi Kpa RES<br />
RDT - RESERVOIR DESC TOOL QPRS PSI KPA QUARTZ GAUGE PRESSURE QGPRES psi Kpa INP<br />
RDT - RESERVOIR DESC TOOL SVD PPS Solenoid Valve D PPSSVD TEL<br />
RDT - RESERVOIR DESC TOOL C14 CURVE 14 C14 INP<br />
RDT - RESERVOIR DESC TOOL C29 CURVE 29 C29 INP<br />
RDT - RESERVOIR DESC TOOL C28 CURVE 28 C28 INP<br />
RDT - RESERVOIR DESC TOOL C27 CURVE 27 C27 INP<br />
RDT - RESERVOIR DESC TOOL C26 CURVE 26 C26 INP<br />
RDT - RESERVOIR DESC TOOL C25 CURVE 25 C25 INP<br />
RDT - RESERVOIR DESC TOOL C24 CURVE 24 C24 INP<br />
RDT - RESERVOIR DESC TOOL C23 CURVE 23 C23 INP<br />
RDT - RESERVOIR DESC TOOL C22 CURVE 22 C22 INP<br />
RDT - RESERVOIR DESC TOOL C21 CURVE 21 C21 INP<br />
RDT - RESERVOIR DESC TOOL C20 CURVE 20 C20 INP<br />
RDT - RESERVOIR DESC TOOL C2 CURVE 2 C2 INP<br />
RDT - RESERVOIR DESC TOOL C19 CURVE 19 C19 INP<br />
RDT - RESERVOIR DESC TOOL C3 CURVE 3 C3 INP<br />
RDT - RESERVOIR DESC TOOL C16 CURVE 16 C16 INP<br />
RDT - RESERVOIR DESC TOOL C17 CURVE 17 C17 INP<br />
RDT - RESERVOIR DESC TOOL C13 CURVE 13 C13 INP<br />
RDT - RESERVOIR DESC TOOL C12 CURVE 12 C12 INP<br />
9-28 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
RDT - RESERVOIR DESC TOOL FPRE PSI PSI FORMATION PRESSURE FPRE PSI PSI INP<br />
RDT - RESERVOIR DESC TOOL C10 CURVE 10 C10 INP<br />
RDT - RESERVOIR DESC TOOL BINS Bins 1-32 BINS INP<br />
RDT - RESERVOIR DESC TOOL BBLP PSI KPA BUBBLE POINT BBLPNT psi Kpa INP<br />
RDT - RESERVOIR DESC TOOL B1 B1 SENSOR B1 INP<br />
RDT - RESERVOIR DESC TOOL AUXV SURFACE AUX VOLTAGE AUXVLT TEL<br />
RDT - RESERVOIR DESC TOOL AUXC SURFACE AUX CURRENT AUXCUR TEL<br />
RDT - RESERVOIR DESC TOOL ATIM ASCII ELAPSED TIME A_TIME RES<br />
RDT - RESERVOIR DESC TOOL HMOB HORIZONTAL MOBILITY MPTHH INP<br />
RDT - RESERVOIR DESC TOOL RELC Relative Capacitance RELCAP TEL<br />
RDT - RESERVOIR DESC TOOL C18 CURVE 18 C18 INP<br />
RDT - RESERVOIR DESC TOOL FIDV V V FLUID ID VOLTS(Volts) FLVOLT V V INP<br />
RDT - RESERVOIR DESC TOOL HLOS HPS LOW OIL SWITCH HPSLOS INP<br />
RDT - RESERVOIR DESC TOOL HI HYDROGEN INDEX HI INP<br />
RDT - RESERVOIR DESC TOOL C15 CURVE 15 C15 INP<br />
RDT - RESERVOIR DESC TOOL C30 CURVE 30 C30 INP<br />
RDT - RESERVOIR DESC TOOL GEOM GEOMETRIC MEAN GEOMM INP<br />
RDT - RESERVOIR DESC TOOL GAIN GAIN GAIN INP<br />
RDT - RESERVOIR DESC TOOL FTEM DEGF DEGC FLUID TEMPERATURE TEMP1 degF degC TEL<br />
RDT - RESERVOIR DESC TOOL FREQ FREQUENCY FREQ TEL<br />
RDT - RESERVOIR DESC TOOL FMSR FPS MOTOR START RELAY FPSMSR TEL<br />
RDT - RESERVOIR DESC TOOL FLPH DEG DEG FLUID ID PHASE FLPHI DEG deg INP<br />
RDT - RESERVOIR DESC TOOL FIDI MA MA FLUID ID CURRENT (mA) FLAMP mA mA INP<br />
RDT - RESERVOIR DESC TOOL EVNT PTA EVENT STRING EVENT INP<br />
RDT - RESERVOIR DESC TOOL ERES OHMM OHMM ESTIMATED RESISTIVITY ERES ohm.m ohm.m INP<br />
RDT - RESERVOIR DESC TOOL ECHN Echo Noise ECHONS TEL<br />
RDT - RESERVOIR DESC TOOL C8 CURVE 8 C8 INP<br />
RDT - RESERVOIR DESC TOOL C31 CURVE 31 C31 INP<br />
RDT - RESERVOIR DESC TOOL C32 CURVE 32 C32 INP<br />
RDT - RESERVOIR DESC TOOL C4 CURVE 4 C4 INP<br />
RDT - RESERVOIR DESC TOOL FLTC FAULT CURRENT FLTCUR TEL<br />
RDT - RESERVOIR DESC TOOL DIEL DIELECTRIC CAPACITANCE DIELCP TEL<br />
RDT - RESERVOIR DESC TOOL C6 CURVE 6 C6 INP<br />
RDT - RESERVOIR DESC TOOL C7 CURVE 7 C7 INP<br />
RDT - RESERVOIR DESC TOOL C5 CURVE 5 C5 INP<br />
RDT - RESERVOIR DESC TOOL C9 CURVE 9 C9 INP<br />
RDT - RESERVOIR DESC TOOL CPRS 1/PSI 1/PSI COMPRESSIBLITY CMPRSS 1/PSI 1/PSI INP<br />
RDT - RESERVOIR DESC TOOL CPV CVS FLUID PURGE VALVE CVSFPV TEL<br />
RDT - RESERVOIR DESC TOOL CV1 CVS Chamber Valve 1 CVSCV1 TEL<br />
RDT - RESERVOIR DESC TOOL CV2 CVS Chamber Valve 2 CVSCV2 TEL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
OAIN OXYGEN ACT INDICATOR NEAR OAI1 RES<br />
OAIF OXYGEN ACT INDICATOR FAR OAI2 RES<br />
RCAP RATIO TOTAL CAPTURE RCAP RES<br />
OBIN OXYGEN BKG INDICATOR NEAR OBI1 RES<br />
o194 OIN CHANNEL 194 OIN194 RES<br />
oi68 OIN CHANNEL 68 OIN68 RES<br />
Mnemonics 9-29<br />
Type_<br />
Data
Serv_Name<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
o114 OIN CHANNEL 114 OIN114 RES<br />
OBIF OXYGEN BKG INDICATOR FAR OBI2 RES<br />
RNFC RATIO NEAR INEL TO NEAR COUNTS RICN RES<br />
SIAF SILICON ACT INDICATOR FAR SIA2 RES<br />
SIIN SILICON INDICATOR NEAR SIIC1 RES<br />
SIIF SILICON INDICATOR FAR SIIC2 RES<br />
NTIM ACCUMULATION TIME NEAR TIME_N RES<br />
LMOD LOGGING MODE LMODE PAR<br />
SICF SULPHUR INDICATOR FAR SIC2 RES<br />
SICN SULPHUR INDICATOR NEAR SIC1 RES<br />
SIAN SILICON ACT INDICATOR NEAR SIA1 RES<br />
NGAI NEAR GAIN NGAIN RES<br />
LIY1 LITH YIELD RAT INEL NEAR LIYR1 RES<br />
LIY2 LITH YIELD RAT INEL FAR LIYR2 RES<br />
YSI1 SILICON YIELD CAPT. NEAR YSI1 RES<br />
STUF STATISTIC UNCERTAINTY FAR STUN2 RES<br />
NBAC NEAR BACKGROUND SPECTRUM NBACK INP<br />
NCAC NEAR CAPTURE SPECTRUM CORR NCAPAC INP<br />
NBAK NEAR BACKGROUND SPECTRUM NBACK INP<br />
NFEC NEAR IRON CHANNEL NFECH RES<br />
NSPT NEAR SPECTRA SUM NSPT RES<br />
NGAO NEAR GAIN OK NGAOK RES<br />
NHCH NEAR HYDROGEN CHANNEL NHCH RES<br />
NINC NEAR INELASTIC SPECTRUM CORR NINELC INP<br />
NINE NEAR INELASTIC SPECTRUM NINEL INP<br />
NOFO NEAR OFFSET OK NOFOK RES<br />
NOFS NEAR OFFSET NOFST RES<br />
NCAP NEAR CAPTURE SPECTRUM NCAP INP<br />
YMG2 MAGNESIUM YIELD CAPT. FAR YMG2 RES<br />
YIC2 CALCIUM YIELD INEL FAR YICA2 RES<br />
YIO1 OXYGEN YIELD INEL NEAR YIO1 RES<br />
YIO2 OXYGEN YIELD INEL FAR YIO2 RES<br />
YIS1 SILICON YIELD INEL NEAR YISI1 RES<br />
9-30 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
YIS2 SILICON YIELD INEL FAR YISI2 RES<br />
YK1 POTASSIUM YIELD CAPT. NEAR YK1 RES<br />
YS1 SULPHUR YIELD CAPT. NEAR YS1 RES<br />
YMG1 MAGNESIUM YIELD CAPT. NEAR YMG1 RES<br />
YH1 HYDROGEN YIELD CAPT. NEAR YH1 RES<br />
YS2 SULPHUR YIELD CAPT. FAR YS2 RES<br />
YSI2 SILICON YIELD CAPT. FAR YSI2 RES<br />
YTI1 TITANIUM YIELD CAPT. NEAR YTI1 RES<br />
YTI2 TITANIUM YIELD CAPT. FAR YTI2 RES<br />
LIRN LITH INDEX INEL NEAR LIRI1 RES<br />
FGAI FAR GAIN FGAIN RES<br />
YK2 POTASSIUM YIELD CAPT. FAR YK2 RES<br />
YCA2 CALCIUM YIELD CAPT. FAR YCA2 RES<br />
TCCF TOTAL COUNTS FAR TCCR2 RES<br />
TCCN TOTAL COUNTS NEAR TCCR1 RES<br />
TNGC NEAR SPACED GATES CORR TNGTC INP<br />
TNGT NEAR SPACED GATES TNGT INP<br />
TNGT NEAR SPACED GATES TNGT INP<br />
YC1 CARBON YIELD INEL NEAR YIC1 RES<br />
YIC1 CALCIUM YIELD INEL NEAR YICA1 RES<br />
YCA1 CALCIUM YIELD CAPT. NEAR YCA1 RES<br />
YH2 HYDROGEN YIELD CAPT. FAR YH2 RES<br />
YCL1 CHLORINE YIELD CAPT. NEAR YCL1 RES<br />
YCL2 CHLORINE YIELD CAPT. FAR YCL2 RES<br />
YEX1 EXTRA YIELD CAPT. NEAR YEX1 RES<br />
YEX2 EXTRA YIELD CAPT. FAR YEX2 RES<br />
YFE1 IRON YIELD CAPT. NEAR YFE1 RES<br />
YFE2 IRON YIELD CAPT. FAR YFE2 RES<br />
STUN STATISTIC UNCERTAINTY NEAR STUN1 RES<br />
YC2 CARBON YIELD INEL FAR YIC2 RES<br />
ERIN RATIO NEAR/ FAR INELASTIC EVR ERIN RES<br />
FEIN IRON INDICATOR NEAR FEIC1 RES<br />
CRAF COMPTON RATIO FAR CRAT2 RES<br />
Mnemonics 9-31<br />
Type_<br />
Data
Serv_Name<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
CRAN COMPTON RATIO NEAR CRAT1 RES<br />
EFCA FAR COUNTRATE EVR EFCA RES<br />
EFSI FAR INELASTIC COUNTS EVR EFSI RES<br />
ENCA NEAR COUNTRATE EVR ENCA RES<br />
COYF C0 YIELD RAT INEL FAR COYR2 RES<br />
ERIC RATIO FAR INEL/FAR COUNTS EVR ERIC RES<br />
COIN CO RATIO INELASTIC NEAR COIR1 RES<br />
ERNF RATIO NEAR / FAR - EVR ERNF RES<br />
ESGI CU CU FAR FORMATION SIGMA EVR ESGF RES<br />
ESGN CU CU NEAR FORMATION SIGMA EVR ESGN RES<br />
FBAC FAR BACKGROUND SPECTRUM FBACK INP<br />
FCAP FAR CAPTURE SPECTRUM FCAP INP<br />
FCPC FAR CAPTURE SPECTRUM CORR FCAPAC INP<br />
FEIF IRON INDICATOR FAR FEIC2 RES<br />
ENSI NEAR INELASTIC COUNTS EVR ENSI RES<br />
AFTN NEAR FORMATION AMPLITUDE AFTN RES<br />
1780 SILICON CHANNEL E1780 RES<br />
2220 HYDROGEN CHANNEL E2220 RES<br />
3730 CALCIUM CHANNEL E3730 RES<br />
4440 CARBON CHANNEL E4440 RES<br />
6100 OXYGEN CHANNEL E6100 RES<br />
7140 OXYGEN FIRST ESCAPE CHANNEL E7140 RES<br />
COYN C0 YIELD RAT INEL NEAR COYR1 RES<br />
AFTF FAR FORMATION AMPLITUDE AFTF RES<br />
CFT1 CAPTURE FIT ERROR NEAR CFTR1 RES<br />
FHCH FAR HYDROGEN CHANNEL FHCH RES<br />
CAIN CALCIUM INDICATOR NEAR CAIC1 RES<br />
LIRF LITH INDEX INEL FAR LIRI2 RES<br />
CFT2 CAPTURE FIT ERROR FAR CFTR2 RES<br />
CLIF CHLORINE INDICATOR FAR CLIC2 RES<br />
CLIN CHLORINE INDICATOR NEAR CLIC1 RES<br />
COIF CO RATIO INELASTIC FAR COIR2 RES<br />
7650 IRON CHANNEL E7650 RES<br />
9-32 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
IR10 LOG RATIO TOTAL INELASTIC IRIN10 RES<br />
HPLN HYDROGEN PEAK NEAR HPLI1 RES<br />
IFT2 INELASTIC FIT ERROR FAR IFTR2 RES<br />
FERF IRON PEAK FAR FERC2 RES<br />
INC2 INCA FAR INCA2 RES<br />
INC2 INCA FAR INCA2 RES<br />
INX1 INOXY NEAR INOX1 RES<br />
HPLF HYDROGEN PEAK FAR HPLI2 RES<br />
IONI MA MA ION CURRENT IONI MA MA INP<br />
IFT1 INELASTIC FIT ERROR NEAR IFTR1 RES<br />
IRIN RATIO TOTAL INELASTIC IRIN RES<br />
ITCF INELASTIC TOTAL COUNTS FAR ITCR2 RES<br />
ITCN INELASTIC TOTAL COUNTS NEAR ITCR1 RES<br />
KAT1 KATO NEAR KATO1 RES<br />
KAT2 KATO FAR KATO2 RES<br />
CAIF CALCIUM INDICATOR FAR CAIC2 RES<br />
INX2 INOXY FAR INOX2 RES<br />
FINC FAR INELASTIC SPECTRUM CORR FINELC INP<br />
FERN IRON PEAK NEAR FERC1 RES<br />
FFEC FAR IRON CHANNEL FFECH RES<br />
KICN POTASSIUM INDICATOR NEAR KIC1 RES<br />
INC1 INCA NEAR INCA1 RES<br />
KICF POTASSIUM INDICATOR FAR KIC2 RES<br />
HICN HYDROGEN INDICATOR NEAR HIC1 RES<br />
FINE FAR INELASTIC SPECTRUM FINEL INP<br />
FOFO FAR OFFSET OK FOFOK RES<br />
FOFS FAR OFFSET FOFST RES<br />
FSPT FAR SPECTRA SUM FSPT RES<br />
FTIM ACCUMULATION TIME FAR TIME_F RES<br />
FTMP DEGF DEGC INTERNAL FLASK TEMPERATURE FTMP degF degC RES<br />
FTRF SPECTRAL FIT ERROR FAR FTR2 RES<br />
FTRN SPECTRAL FIT ERROR NEAR FTR1 RES<br />
HICF HYDROGEN INDICATOR FAR HIC2 RES<br />
Mnemonics 9-33<br />
Type_<br />
Data
Serv_Name<br />
RMT-ELITE - RESERV MON<br />
TOOL<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
FGAO FAR GAIN OK FGAOK RES<br />
SDDT/NAV - DIRECTIONAL AZI1 DEG DEG PAD 1 AZIMUTH AZI1 deg deg RES<br />
SDDT/NAV - DIRECTIONAL MAGQ MAGNETOMETER SUM OF SQUARES MAGQ RES<br />
SDDT/NAV - DIRECTIONAL TEMP DEGC DEGC NAVIGATION TEMPERATURE TEMP degC degC RES<br />
SDDT/NAV - DIRECTIONAL RBX DEG DEG AUXILIARY ROTATION RBX deg deg RES<br />
SDDT/NAV - DIRECTIONAL RB DEG DEG RELATIVE BEARING RB deg deg RES<br />
SDDT/NAV - DIRECTIONAL MAGZ MAGNETOMETER Z-AXIS MAGZ RES<br />
SDDT/NAV - DIRECTIONAL MAGX MAGNETOMETER X-AXIS MAGX RES<br />
SDDT/NAV - DIRECTIONAL AX G G ACCELEROMETER X-AXIS AX G G RES<br />
SDDT/NAV - DIRECTIONAL HAZI DEG DEG DRIFT / HOLE AZIMUTH HAZI deg deg RES<br />
SDDT/NAV - DIRECTIONAL MAGY MAGNETOMETER Y-AXIS MAGY RES<br />
SDDT/NAV - DIRECTIONAL ACCQ ACCELEROMETER SUM OF SQUARES ACCQ RES<br />
SDDT/NAV - DIRECTIONAL AY G G ACCELEROMETER Y-AXIS AY G G RES<br />
SDDT/NAV - DIRECTIONAL AZ G G ACCELEROMETER Z-AXIS AZ G G RES<br />
SDDT/NAV - DIRECTIONAL AZI1 DEG DEG REFERENCED AZIMUTH AZI1 deg deg RES<br />
SDDT/NAV - DIRECTIONAL AZIX DEG DEG AUXILIARY AZIMUTH AZIX deg deg RES<br />
SDDT/NAV - DIRECTIONAL DEVI DEG DEG DRIFT ANGLE DEVI deg deg RES<br />
SDDT/NAV - DIRECTIONAL DXTM MS MS Z-ACCELEROMETER, TIME BASE DXTM mS mS INP<br />
SDL - SPECTRAL DENSITY NAB CPS CPS NEAR ABOVE NAB 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY NHV V V NEAR HIGH VOLTAGE NHV V V INP<br />
SDL - SPECTRAL DENSITY NLU CPS CPS NEAR LITHOLOGY UNFILTERED NLIU 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY NLO CPS CPS NEAR CESIUM LOW NLO 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY NLIU CPS CPS NEAR LITHOLOGY UNFILTERED NLIU 1.0/S 1.0/S INP<br />
SDL - SPECTRAL DENSITY NLI CPS CPS NEAR LITHOLOGY NLI 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY NPK CPS CPS NEAR PEAK NPK 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY NHI CPS CPS NEAR CESIUM HI NHI 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY NDE CPS CPS NEAR DENSITY NDE 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY NVA CPS CPS NEAR VALLEY NVA 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY NBA CPS CPS NEAR BARITE NBA 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY QF FAR QUALITY QF RES<br />
SDL - SPECTRAL DENSITY M5AN V V MINUS 5 VOLTS ANALOG MI5AN V V INP<br />
SDL - SPECTRAL DENSITY M15V V V MINUS 15 VOLTS MI15V V V INP<br />
SDL - SPECTRAL DENSITY LDWC HSDL LS DENSITY WINDOW COUNTS LDENWD RES<br />
SDL - SPECTRAL DENSITY NBAU CPS CPS NEAR BARITE UNFILTERED NBAU 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY QS SDL QUALITY SHORT QS RES<br />
SDL - SPECTRAL DENSITY SPWC HSDL SS PEAK WINDOW COUNTS SPEKWD RES<br />
SDL - SPECTRAL DENSITY SLWC HSDL SS LITH. WINDOW COUNTS SLITWD RES<br />
SDL - SPECTRAL DENSITY SDWC HSDL SS DENSITY WINDOW COUNTS<br />
SDENW<br />
D<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
SDL - SPECTRAL DENSITY SDSO IN MM SDL STANDOFF SDSO in mm RES<br />
SDL - SPECTRAL DENSITY SDC1 INCH MM SDL PAD CALIPER CALIP in mm TEL<br />
SDL - SPECTRAL DENSITY SBWC HSDL SS BARITE WINDOW COUNTS SBARWD RES<br />
SDL - SPECTRAL DENSITY PRTM C C PRE-REG. TEMPERATURE PRTMP C C INP<br />
SDL - SPECTRAL DENSITY REF5 V V 5 VOLT REFERENCE REF5 V V INP<br />
SDL - SPECTRAL DENSITY P15V VOLT VOLT PLUS 15 VOLTS P15 V V TEL<br />
SDL - SPECTRAL DENSITY QN NEAR QUALITY QN RES<br />
SDL - SPECTRAL DENSITY QL SDL QUALITY LONG QL RES<br />
SDL - SPECTRAL DENSITY PTMP PAD TEMPERATURE PTMP TEL<br />
SDL - SPECTRAL DENSITY LBWC HSDL LS BARITE WINOW COUNTS LBARWD RES<br />
9-34 Mnemonics<br />
Type_<br />
Data<br />
RES
Serv_Name<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
SDL - SPECTRAL DENSITY PE PHOTO-ELECTRIC FACTOR PE RES<br />
SDL - SPECTRAL DENSITY P5AN V V Plus 5 Volts Analog PL5AN V V INP<br />
SDL - SPECTRAL DENSITY RHOB G/C3 K/M3 BULK DENSITY RHOB g/cm3 Kg/m3 RES<br />
SDL - SPECTRAL DENSITY DLIM DECP DECP DENSITY POROSITY, LIMESTONE DLIM 100 pu 100 pu RES<br />
SDL - SPECTRAL DENSITY EDLI DECP DECP DENSITY POROSITY LIME, EVR EDLI 100 pu 100 pu RES<br />
SDL - SPECTRAL DENSITY EDCT G/CC K/M3 EVR DENSITY CORRECTION TOTAL EDCT GM/CC KG/M3 RES<br />
SDL - SPECTRAL DENSITY EDCP G/CC K/M3 EVR DENSITY CORRECTION POS. EDCP GM/CC KG/M3 RES<br />
SDL - SPECTRAL DENSITY EDCN G/CC K/M3 EVR DENSITY CORRECTION NEG. EDCN GM/CC KG/M3 RES<br />
SDL - SPECTRAL DENSITY DRHO G/C3 K/M3 DENSITY CORRECTION DRHO g/cm3 Kg/m3 RES<br />
SDL - SPECTRAL DENSITY DPHS DECP DECP DENSITY POROSITY, SANDSTONE DPHS 100 pu 100 pu RES<br />
SDL - SPECTRAL DENSITY EDMF EVR MINIMUM FILTERING EDMF RES<br />
SDL - SPECTRAL DENSITY DPHD DECP DECP DENSITY POROSITY, DOLOMITE DPHD 100 pu 100 pu RES<br />
SDL - SPECTRAL DENSITY DPE PE CORRECTION DPE RES<br />
SDL - SPECTRAL DENSITY DCOM DENSITY CORRECTION MINUS DCOR_M RES<br />
SDL - SPECTRAL DENSITY DC10 V V DCB 10 Volt Reference DCB10 V V INP<br />
SDL - SPECTRAL DENSITY CORP DENSITY CORRECTION PLUS CORP RES<br />
SDL - SPECTRAL DENSITY 5VD V V 5 Volt 5VD V V INP<br />
SDL - SPECTRAL DENSITY CORM DENSITY CORRECTION MINUS CORM RES<br />
SDL - SPECTRAL DENSITY ITMP INSTRUMENT TEMPERATURE ITMP TEL<br />
SDL - SPECTRAL DENSITY PROU V V Pre Reg OUT PROUT V V INP<br />
SDL - SPECTRAL DENSITY DPHI DECP DECP DENSITY POROSITY DPHI 100 pu 100 pu RES<br />
SDL - SPECTRAL DENSITY FDE CPS CPS FAR DENSITY FDE 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY DCOP DENSITY CORRECTION PLUS DCOR_P RES<br />
SDL - SPECTRAL DENSITY EDPD DECP DECP DENSITY POROSITY DOLO, EVR EDPD 100 pu 100 pu RES<br />
SDL - SPECTRAL DENSITY FPK CPS CPS FAR PEAK FPK 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY FLO CPS CPS FAR CESIUM LOW FLO 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY FLI CPS CPS FAR LITHOLOGY FLI 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY FHI CPS CPS FAR CESIUM HIGH FHI 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY FVA CPS CPS FAR VALLEY FVA 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY FBA CPS CPS FAR BARITE FBA 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY EDPS DECP DECP DENSITY POROSITY SAND, EVR EDPS 100 pu 100 pu RES<br />
SDL - SPECTRAL DENSITY EDPH DECP DECP DENSITY POROSITY, EVR EDPH 100 pu 100 pu RES<br />
SDL - SPECTRAL DENSITY FHV V V FAR HIGH VOLTAGE FHV V V INP<br />
SDL - SPECTRAL DENSITY EDPL DECP DECP EVR DENSITY LIME POROSITY EDPL 100 pu 100 pu RES<br />
SDL - SPECTRAL DENSITY FAB CPS CPS FAR ABOVE FAB 1.0/S 1.0/S TEL<br />
SDL - SPECTRAL DENSITY EMPE EVR PE - MIN FILT EMPE RES<br />
SDL - SPECTRAL DENSITY EMRH G/CC KG/M3 EVR BULK DENSITY - MIN FILT EMRH G/CC KG/M3 RES<br />
SDL - SPECTRAL DENSITY EPE PE EVR EPE RES<br />
SDL - SPECTRAL DENSITY EPMF EVR PE MINIMUM FILTERING EPMF RES<br />
SDL - SPECTRAL DENSITY ERHO G/CC KG/M3 BULK DENSITY - EVR PROCESSED ERHO G/CC KG/M3 RES<br />
SED - SIX ELECT DIPMETER PDD2 OHMM OHMM SED PAD #2 RESISTIVITY (FAST) PDD2 ohm.m ohm.m RES<br />
SED - SIX ELECT DIPMETER MAGZ MAGNETOMETER Z-AXIS MAGZ RES<br />
SED - SIX ELECT DIPMETER MAGY MAGNETOMETER Y-AXIS MAGY RES<br />
SED - SIX ELECT DIPMETER P2B1 OHMM OHMM SED PAD #2, RESISTIVITY P2B1 ohm.m ohm.m RES<br />
SED - SIX ELECT DIPMETER P3B1 OHMM OHMM SED PAD #3, RESISTIVITY P3B1 ohm.m ohm.m RES<br />
SED - SIX ELECT DIPMETER P4B1 OHMM OHMM SED PAD #4, RESISTIVITY P4B1 ohm.m ohm.m RES<br />
SED - SIX ELECT DIPMETER P5B1 OHMM OHMM SED PAD #5, RESISTIVITY P5B1 ohm.m ohm.m RES<br />
SED - SIX ELECT DIPMETER P6B1 OHMM OHMM SED PAD #6, RESISTIVITY P6B1 ohm.m ohm.m RES<br />
SED - SIX ELECT DIPMETER PDD1 OHMM OHMM SED PAD #1 RESISTIVITY (FAST) PDD1 ohm.m ohm.m RES<br />
Mnemonics 9-35<br />
Type_<br />
Data
Serv_Name<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
SED - SIX ELECT DIPMETER P1B1 OHMM OHMM SED PAD #1 RESISTIVITY P1B1 ohm.m ohm.m RES<br />
SED - SIX ELECT DIPMETER PDD3 OHMM OHMM SED PAD #3 RESISTIVITY (FAST) PDD3 ohm.m ohm.m RES<br />
SED - SIX ELECT DIPMETER PDD4 OHMM OHMM SED PAD #4 RESISTIVITY (FAST) PDD4 ohm.m ohm.m RES<br />
SED - SIX ELECT DIPMETER PDD5 OHMM OHMM SED PAD #5 RESISTIVITY (FAST) PDD5 ohm.m ohm.m RES<br />
SED - SIX ELECT DIPMETER PDD6 OHMM OHMM SED PAD #6 RESISTIVITY (FAST) PDD6 ohm.m ohm.m RES<br />
SED - SIX ELECT DIPMETER PDDV V V SED PAD VOLTAGE PDDV V V RES<br />
SED - SIX ELECT DIPMETER PRES SED PAD FORCE PRES RES<br />
SED - SIX ELECT DIPMETER RB DEG DEG PAD #1 ROTATION RB deg deg RES<br />
SED - SIX ELECT DIPMETER ZACC G G SED Z ACCELEROMETER (FAST) ZACC G G RES<br />
SED - SIX ELECT DIPMETER MAGX MAGNETOMETER X-AXIS MAGX RES<br />
SED - SIX ELECT DIPMETER F2B1 SED PAD #2, PROFILE 1 (FAST) F2B1 RES<br />
SED - SIX ELECT DIPMETER TEMP DEGC DEGC NAVIGATION TEMPERATURE TEMP degC degC RES<br />
SED - SIX ELECT DIPMETER CAL3 IN MM SED CALIPER ARM #3 (RADIUS X2) CAL3 in mm RES<br />
SED - SIX ELECT DIPMETER ACCX G G ACCELEROMETER X-AXIS ACCX G G RES<br />
SED - SIX ELECT DIPMETER ACCY G G ACCELEROMETER Y-AXIS ACCY G G RES<br />
SED - SIX ELECT DIPMETER F4B1 SED PAD #4, PROFILE 1 (FAST) F4B1 RES<br />
SED - SIX ELECT DIPMETER MAGQ MAGNETOMETER SUM OF SQUARES MAGQ RES<br />
SED - SIX ELECT DIPMETER C14 IN MM SED CALIPER PAIR 1-4 C14 in mm RES<br />
SED - SIX ELECT DIPMETER C25 IN MM SED CALIPER PAIR 2-5 C25 in mm RES<br />
SED - SIX ELECT DIPMETER C36 IN MM SED CALIPER PAIR 3-6 C36 in mm RES<br />
SED - SIX ELECT DIPMETER CAL2 IN MM SED CALIPER ARM #2 (RADIUS X2) CAL2 in mm RES<br />
SED - SIX ELECT DIPMETER CAL4 IN MM SED CALIPER ARM #4 (RADIUS X2) CAL4 in mm RES<br />
SED - SIX ELECT DIPMETER CAL5 IN MM SED CALIPER ARM #5 (RADIUS X2) CAL5 in mm RES<br />
SED - SIX ELECT DIPMETER CAL6 IN MM SED CALIPER ARM #6 (RADIUS X2) CAL6 in mm RES<br />
SED - SIX ELECT DIPMETER F5B1 SED PAD #5, PROFILE 1 (FAST) F5B1 RES<br />
SED - SIX ELECT DIPMETER DEVI DEG DEG DRIFT ANGLE DEVI deg deg RES<br />
SED - SIX ELECT DIPMETER DMAX IN MM SED MAXIMUM CALIPER PAIR DMAX in mm RES<br />
SED - SIX ELECT DIPMETER DMIN IN MM SED MINIMUM CALIPER PAIR DMIN in mm RES<br />
SED - SIX ELECT DIPMETER DXTM 08.3MS 08.3MS SED Z-ACCELEROMETER, TIME BASE DXTM 8.3 mS 8.3 mS INP<br />
SED - SIX ELECT DIPMETER F1B1 SED PAD #1, PROFILE 1 (FAST) F1B1 RES<br />
SED - SIX ELECT DIPMETER F3B1 SED PAD #3, PROFILE 1 (FAST) F3B1 RES<br />
SED - SIX ELECT DIPMETER CALA IN MM SED AVERAGE CALIPER CALA in mm RES<br />
SED - SIX ELECT DIPMETER CAL1 IN MM SED CALIPER ARM #1 (RADIUS X2) CAL1 in mm RES<br />
SED - SIX ELECT DIPMETER HAZI DEG DEG DRIFT AZIMUTH HAZI deg deg RES<br />
SED - SIX ELECT DIPMETER F6B1 SED PAD #6, PROFILE 1 (FAST) F6B1 RES<br />
SFT - SEQ FORM TESTER STTF DEGF DEGF SFT TRANSDUCER TEMPERATURE STTF degF degF RES<br />
SFT - SEQ FORM TESTER STTC DEG C DEG C SFT TRANSDUCER TEMP STTC DEG C DEG C RES<br />
SFT - SEQ FORM TESTER SSI SAMPLE SHUTIN LOGICAL SSI RES<br />
SFT - SEQ FORM TESTER SITF DEGF DEGF SFT INSTRUMENT TEMPERATURE SITF degF degF RES<br />
SFT - SEQ FORM TESTER SITC DEGC DEGC SFT INSTRUMENT TEMPERATURE SITC degC degC RES<br />
SFT - SEQ FORM TESTER SDEP FT M SFT SET DEPTH SDEP ft m RES<br />
SFT - SEQ FORM TESTER RPRE PSI KPA STRAIN GAUGE PRESSURE RPRE psi Kpa RES<br />
SFT - SEQ FORM TESTER SAMP CC CC PRETEST VOLUME SAMP 0.01 L 0.01 L RES<br />
SFT - SEQ FORM TESTER TENS LB KG LINE TENSION (SURFACE) TENS lbm Kg RES<br />
SFT - SEQ FORM TESTER HSFE HSFT Event HSFE RES<br />
SFT - SEQ FORM TESTER SDD PSI KPA SFT SAMPLE DRAWDOWN SDD psi Kpa RES<br />
SFT - SEQ FORM TESTER TLPS TOOL POSITION TLPS RES<br />
SFT - SEQ FORM TESTER TMIN MN MN TEST TIME MINUTES TMIN min min RES<br />
SFT - SEQ FORM TESTER TPT MN MN PRETEST TIME TPT min min RES<br />
9-36 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
SFT - SEQ FORM TESTER TSAM MN MN SFT SAMPLE TIME TSAM min min RES<br />
SFT - SEQ FORM TESTER TSEC S S SECONDS INTO TEST TSEC S S RES<br />
SFT - SEQ FORM TESTER TSI MN MN SHUTIN TIME TSI min min RES<br />
SFT - SEQ FORM TESTER TTMP DEGF DEGF HSFT TRANSDUCER TEMPERATURE TTMP degF degF RES<br />
SFT - SEQ FORM TESTER STRA PSI KPA STRAIN PRESSURE STRA psi Kpa RES<br />
SFT - SEQ FORM TESTER HYDP PSI KPA HSFT HYDRAULIC PRESSURE HYDP psi Kpa RES<br />
SFT - SEQ FORM TESTER HTF PSI KPA HONER BUILD UP DITS HTF psi Kpa RES<br />
SFT - SEQ FORM TESTER PTTH PSI KPA PRESSURE TEN THOUSANDS PTTH psi Kpa RES<br />
SFT - SEQ FORM TESTER PROD PSI KPA DRAW DOWN PRESSURE PROD psi Kpa RES<br />
SFT - SEQ FORM TESTER DMV V V SFT DOWNHOLE MOTOR VOLTAGE DMV V V RES<br />
SFT - SEQ FORM TESTER KHOR MD MD HORNER PERMEABILITY KHOR mD mD RES<br />
SFT - SEQ FORM TESTER PTHS PSI KPA PRESSURE TENTHS PTHS psi Kpa RES<br />
SFT - SEQ FORM TESTER ATXT ASCII ACTION EVENTS A_TEXT RES<br />
SFT - SEQ FORM TESTER ATIM ASCII ELAPSED TIME A_TIME RES<br />
SFT - SEQ FORM TESTER DIV V V SFT INSTRUMENT VOLTAGE DIV V V RES<br />
SFT - SEQ FORM TESTER FTHU PSI KPA STRAIN PRESSURE HUNDREDS FTHU psi Kpa RES<br />
SFT - SEQ FORM TESTER FTON PSI KPA STRAIN PRESSURE ONES FTON psi Kpa RES<br />
SFT - SEQ FORM TESTER FTTE PSI KPA STRAIN PRESSURE TENS FTTE psi Kpa RES<br />
SFT - SEQ FORM TESTER FTTH PSI KPA STRAIN PRESSURE THOUSANDS FTTH psi Kpa RES<br />
SFT - SEQ FORM TESTER HORT HORNER TIME (DIMENSIONLESS) HORT RES<br />
SFT - SEQ FORM TESTER KD MD MD DRAWDOWN PERMEABILITY KD mD mD RES<br />
SFT - SEQ FORM TESTER PBUP PSI KPA SFT PRETEST BUILDUP PBUP psi Kpa RES<br />
SFT - SEQ FORM TESTER PRDD PSI KPA DRAW DOWN PRESSURE PRDD psi Kpa RES<br />
SFT - SEQ FORM TESTER PTHO PSI KPA PRESSURE THOUSANDS PTHO psi Kpa RES<br />
SFT - SEQ FORM TESTER PHDS PSI KPA PRESSURE HUNDREDTHS PHDS psi Kpa RES<br />
SFT - SEQ FORM TESTER PSBU PSI KPA SAMPLE BUILDUP PSBU psi Kpa RES<br />
SFT - SEQ FORM TESTER PTEN PSI KPA PRESSURE TENS PTEN psi Kpa RES<br />
SFT - SEQ FORM TESTER PRES PSI KPA TOTAL PRESSURE PRES psi Kpa RES<br />
SFT - SEQ FORM TESTER PPSI PSI KPA SFT PREVIOUS SHUT-IN PRESSURE PPSI psi Kpa RES<br />
SFT - SEQ FORM TESTER PPSI PSI KPA SFT PREVIOUS SHUT-IN PRESSURE PPSI psi Kpa RES<br />
SFT - SEQ FORM TESTER PONE PSI KPA SFT PRESSURE ONES PONE psi Kpa RES<br />
SFT - SEQ FORM TESTER PHUN PSI KPA PRESSURE HUNDREDS PHUN psi Kpa RES<br />
SFT - SEQ FORM TESTER PHST PSI KPA SFT HYDROSTATIC PRESSURE PHST psi Kpa RES<br />
SFT - SEQ FORM TESTER PHFL PSI KPA SFT HYDRAULIC PRESSURE PHFL psi Kpa RES<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
RICL ALOG10(RINC) RINCL RES<br />
NSG6 NEAR GATE 6 CNTS UNFILTERED NSG6 RES<br />
QW WATER FLOW RATE QW RES<br />
RIN RATIO NEAR TO FAR INELASTIC RIN RES<br />
PHIT POROSITY FROM NEAR/FAR RATIO PHIT RES<br />
OBI OXYGEN BACKGROUND OBI RES<br />
OB66 OB66 OB66 RES<br />
RINC RATIO N NET INEL TO F NET INEL RINC RES<br />
OAI OXYGEN ACTIVATION OAI RES<br />
RICF RATIO FAR TO FAR COUNTS RICF RES<br />
Mnemonics 9-37<br />
Type_<br />
Data
Serv_Name<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
O194 OA194 OA194 RES<br />
O114 OA114 OA114 RES<br />
NTMD NEAR COUNTRATE NTMD RES<br />
NSG3 NEAR GATE 3 CNTS UNFILTERED NSG3 RES<br />
NSGI NEAR GATE I NSGI RES<br />
NSG5 NEAR GATE 5 CNTS UNFILTERED NSG5 RES<br />
NSG4 NEAR GATE 4 CNTS UNFILTERED NSG4 RES<br />
RINL Log(RIN) RINL RES<br />
SGIN CU CU INTRINSIC FORMATION SIGMA SGIN cu CU RES<br />
NSG2 NEAR GATE 2 CNTS UNFILTERED NSG2 RES<br />
NSG1 NEAR GATE 1CNTS UNFILTERED NSG1 RES<br />
NSIN CU CU NEAR INELASTIC COUNTS NSIN cu CU RES<br />
SGNU NEAR SIGMA STATISTIC SGNU RES<br />
NSBU NEAR BACKGROUND UNFILTERED NSBU RES<br />
INOX OXYGEN VALUE INOX RES<br />
YSI YIELD SILICATE YSI RES<br />
YFE YIELD IRON YFE RES<br />
YCA YIELD CARBONATE YCA RES<br />
Y4 YIELD EXTRA Y4 RES<br />
WBUF Work Space Buffer WBUF RES<br />
TNGT NEAR SPACED UNFILTERED TNGT INP<br />
TNA TOTAL NEAR ACTIVATION TNA RES<br />
TFGT FAR SPACED GATES TFGT INP<br />
SGFN CU CU NEAR FORMATION SIGMA SGFN cu CU RES<br />
TFA TOTAL FAR ACTIVATION TFA RES<br />
ROA RATIO OXYGEN ACTIVATION ROA RES<br />
SGFU FAR SIGMA STATISTIC SGFU RES<br />
SGFM CU CU CORRECTED FORMATION SIGMA SGFM cu CU RES<br />
SGFF CU CU FAR FORMATION SIGMA SGFF cu CU RES<br />
SGBN CU CU NEAR BOREHOLE SIGMA SGBN cu CU RES<br />
SGBF CU CU FAR BOREHOLE SIGMA SGBF cu CU RES<br />
RTMD RATIO NEAR TO FAR COUNTRATE RTMD RES<br />
RTBF RATIO NEAR BORE TO FORM AMP RTBF RES<br />
9-38 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
ROAT RATIO OXYGEN ACTIVATION TOTAL ROAT RES<br />
ROAS RATIO OXY ACTIVATION SPECTRAL ROAS RES<br />
ROAG RATIO OXYGEN ACTIVATION GAMMA ROAG RES<br />
TFGT FAR SPACED UNFILTERED TFGT INP<br />
E510 E510 E510 RES<br />
FACT FAT ACTIVATION SPECTRUM FACT INP<br />
ESGN CU CU EVR SIGMA NEAR ESGN cu CU RES<br />
ESGF CU CU EVR SIGMA FORMATION FAR ESGF cu CU RES<br />
ESFM CU CU EVR SIGMA FORMATION CORRECTED ESFM cu CU RES<br />
ERIN EVR RATIO INEL COUNTS ERIN RES<br />
ERIC EVR RATIO INEL/FS COUNTS ERIC RES<br />
ENTM EVR NEAR COUNTS ENTM RES<br />
EGR GAPI GAPI NATURAL GAMMA RAY - EVR EGR gAPI gAPI RES<br />
EFTM EVR FAR COUNTS EFTM RES<br />
EFSI EVR FAR INELASTIC COUNTS EFSI RES<br />
ECRN EVR CORR RATIO COUNT ECRN RES<br />
FDX FLOW DETECTION INDICATOR FDX RES<br />
E645 OXYGEN CHANNEL - SECOND ESCAPE E645 RES<br />
ERAT EVR RATIO NEAR/FAR COUNTRATE ERAT RES<br />
DSIG DELTA SIGMA FORMATION DSIG RES<br />
DCSF DIFFUSION CORRECTED SIGMA FORM DCSF RES<br />
ABTF FAR BOREHOLE AMPLITUDE ABTF RES<br />
ABTN NEAR BOREHOLE AMPLITUDE ABTN RES<br />
BACK BACKGROUND SPECTRUM BACK INP<br />
BKSM SPECTRUM SUMS BKSM RES<br />
BORE BOREHOLE SPECTRUM BORE INP<br />
CRAT COMPTON RATIO CRAT RES<br />
CRNF CORRECTED RATIO CRNF RES<br />
ITMP DEGF DEGC INTERNAL INSTRUMENT TEMPERATUR ITMP degF degC RES<br />
NSBF NEAR BACKGROUND FILTERED NSBF RES<br />
E665 IRON EDGE E665 RES<br />
INCA CATION VALUE INCA RES<br />
NNIN NEAR NET INELASTIC COUNT RATE NNIN RES<br />
Mnemonics 9-39<br />
Type_<br />
Data
Serv_Name<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
TMD-L - THERMAL MULTIGATE<br />
DECAY<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
NFTR NEAR FIT ERROR NFTR RES<br />
NACT NEAR ACTIVATION SPECTRUM NACT INP<br />
KATO RATIO CATION/OXYGEN VALUE KATO RES<br />
ENSI EVR NEAR INELASTIC COUNTS ENSI RES<br />
INEL INELASTIC SPECTRUM INEL INP<br />
FFTR FAR FIT ERROR FFTR RES<br />
GRA API API GAMMA RAY TMD FILTERED GRA gAPI gAPI RES<br />
GENV VOLTS VOLTS GENERATOR VOLTS GENV VOLTS VOLTS INP<br />
FVT FLOW VELOCITY TOTAL FVT RES<br />
FVS FLOW VELOCITY SPECTRAL FVS RES<br />
FVG FLOW VELOCITY GAMMA FVG RES<br />
FV FLOW VELOCITY FV RES<br />
FTMD FAR COUNTRATE FTMD RES<br />
FSG1 FAR GATE 1 CNTS UNFILTERED FSG1 RES<br />
FNIN FAR NET INELASTIC COUNT RATE FNIN RES<br />
IONI MA MA ION CURRENT IONI MA MA INP<br />
FSIN FAR INELASTIC COUNTS FSIN RES<br />
FORM FORMATION SPECTRUM FORM INP<br />
FSBU FAR BACKGROUND UNFILTERED FSBU RES<br />
FSG2 FAR GATE 2 CNTS UNFILTERED FSG2 RES<br />
FSG3 FAR GATE 3 CNTS UNFILTERED FSG3 RES<br />
FSG4 FAR GATE 4 CNTS UNFILTERED FSG4 RES<br />
FSG5 FAR GATE 5 CNTS UNFILTERED FSG5 RES<br />
FSG6 FAR GATE 6 CNTS UNFILTERED FSG6 RES<br />
FSGI FAR GATE I FSGI RES<br />
FSBF FAR BACKGROUND FILTERED FSBF RES<br />
WSTT - WAVESONIC SBY Y B-D PRES WAVEFORM SEMBLANCE SBY INP<br />
WSTT - WAVESONIC YSBP Y SEMBLANCE VALUE OF PEAK YSBP INP<br />
WSTT - WAVESONIC SBX X A-C PRES WAVEFORM SEMBLANCE SBX INP<br />
WSTT - WAVESONIC SPHI DECP DECP SONIC POROSITY SPHI 100 pu 100 pu RES<br />
WSTT - WAVESONIC VPVX VELOCITY RATIO X VPVX INP<br />
WSTT - WAVESONIC VPVY VELOCITY RATIO Y VPVY INP<br />
WSTT - WAVESONIC WVST XACT FORMAT DATA STRUCTURE WVST INP<br />
WSTT - WAVESONIC XDT2 X DIPOLE PEAK SLOWNESS 2 XDT2 INP<br />
WSTT - WAVESONIC XSBP X SEMBLANCE VALUE OF PEAK XSBP INP<br />
WSTT - WAVESONIC XSH X DIPOLE UPPER SLOWNESS XSH INP<br />
9-40 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
WSTT - WAVESONIC XSL X DIPOLE LOWER SLOWNESS XSL INP<br />
WSTT - WAVESONIC YDT Y DIPOLE PEAK SLOWNESS YDT INP<br />
WSTT - WAVESONIC YMUT Y DIPOLE MUTE YMUT INP<br />
WSTT - WAVESONIC YSH Y DIPOLE UPPER SLOWNESS YSH INP<br />
WSTT - WAVESONIC YSL Y DIPOLE LOWER SLOWNESS YSL INP<br />
WSTT - WAVESONIC XDT X DIPOLE PEAK SLOWNESS XDT INP<br />
WSTT - WAVESONIC SBM MONO PRES WAVEFORM SEMBLANCE SBM INP<br />
WSTT - WAVESONIC YDT2 Y DIPOLE PEAK SLOWNESS 2 YDT2 INP<br />
WSTT - WAVESONIC DXRV DIPOLE X WAVE RIGHT VALUE DXRV INP<br />
WSTT - WAVESONIC PRY POISSON"S RATIO Y PRY INP<br />
WSTT - WAVESONIC XMUT X DIPOLE MUTE XMUT INP<br />
WSTT - WAVESONIC DXLV DIPOLE X WAVE LEFT VALUE DXLV INP<br />
WSTT - WAVESONIC DPSY DIPOLE SOURCE Y STRUCTURE DPSY INP<br />
WSTT - WAVESONIC DPSX DIPOLE SOURCE X STRUCTURE DPSX INP<br />
WSTT - WAVESONIC D2CT DIPOLE 2 COMPRESSED WORD COUNT D2CT INP<br />
WSTT - WAVESONIC D1CT DIPOLE 1 COMPRESSED WORD COUNT D1CT INP<br />
WSTT - WAVESONIC ACQN ACQUISITION NUMBER ACQN INP<br />
WSTT - WAVESONIC DXXW X DIPOLE A-C #1 PRES WAVEFORM DXXW INP<br />
WSTT - WAVESONIC DYLV DIPOLE Y LEFT VALUE DYLV INP<br />
WSTT - WAVESONIC DYRV DIPOLE Y RIGHT VALUE DYRV INP<br />
WSTT - WAVESONIC DYYW Y DIPOLE B-D #1 PRES WAVEFORM DYYW INP<br />
WSTT - WAVESONIC FAZI DIRECTION OF FAST SHEAR WAVE FAZI INP<br />
WSTT - WAVESONIC MSH MONOPOLE UPPER SLOWNESS MSH INP<br />
WSTT - WAVESONIC PNSA % ANISOTROPY PNSA INP<br />
WSTT - WAVESONIC PRX POISSON"S RATIO X PRX INP<br />
WSTT - WAVESONIC CONF CONFIDENCE OF THE MEASUREMENT CONF INP<br />
WSTT - WAVESONIC MCNT MONOPOLE COMPRESSED WORD COUNT MCNT INP<br />
WSTT - WAVESONIC MWRV MONOPOLE WAVE RIGHT VALUE MWRV INP<br />
WSTT - WAVESONIC MSL MONOPOLE LOWER SLOWNESS MSL INP<br />
WSTT - WAVESONIC MWV MONOPOLE REC #1 PRES WAVEFORM MWV INP<br />
WSTT - WAVESONIC MSBP MONO SEMBLANCE VALUE OF PEAK MSBP INP<br />
WSTT - WAVESONIC MMUT MONOPOLE MUTE MMUT INP<br />
WSTT - WAVESONIC MIT MIT mode MITMOD INP<br />
WSTT - WAVESONIC MDT2 MONOPOLE PEAK SLOWNESS 2 MDT2 INP<br />
WSTT - WAVESONIC MDT MONOPOLE PEAK SLOWNESS MDT INP<br />
WSTT - WAVESONIC MWLV MONOPOLE WAVE LEFT VALUE MWLV INP<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
OMIS NESW NESW VIEW BUTTONS IMAGE (N-E-S-W-N) OMIS NESW NESW RES<br />
OMI4 OHMM OHMM OMI #4 - FAST BUTTON ARRAY OMI4 ohm.m ohm.m RES<br />
P1B1 OHMM OHMM PAD #1 RESISTIVITY P1B1 ohm.m ohm.m RES<br />
OMI6 OHMM OHMM OMI #6 - FAST BUTTON ARRAY OMI6 ohm.m ohm.m RES<br />
OMI5 OHMM OHMM OMI #5 - FAST BUTTON ARRAY OMI5 ohm.m ohm.m RES<br />
OMI3 OHMM OHMM OMI #3 - FAST BUTTON ARRAY OMI3 ohm.m ohm.m RES<br />
OMI2 OHMM OHMM OMI #2 - FAST BUTTON ARRAY OMI2 ohm.m ohm.m RES<br />
OMI1 OHMM OHMM OMI #1 - FAST BUTTON ARRAY OMI1 ohm.m ohm.m RES<br />
ITMP DEGF DEGC INTERNAL TEMPERATURE ITMP degF degC RES<br />
Mnemonics 9-41<br />
Type_<br />
Data
Serv_Name<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
F5B1 SED PAD #5, PROFILE 1 (FAST) F5B1 RES<br />
P2B1 OHMM OHMM PAD #2 RESISTIVITY P2B1 ohm.m ohm.m RES<br />
ZACC G G Z ACCELEROMETER (FAST) ZACC G G RES<br />
F6B1 SED PAD #6, PROFILE 1 (FAST) F6B1 RES<br />
P3B1 OHMM OHMM PAD #3 RESISTIVITY P3B1 ohm.m ohm.m RES<br />
P4B1 OHMM OHMM PAD #4 RESISTIVITY P4B1 ohm.m ohm.m RES<br />
P5B1 OHMM OHMM PAD #5 RESISTIVITY P5B1 ohm.m ohm.m RES<br />
P6B1 OHMM OHMM PAD #6 RESISTIVITY P6B1 ohm.m ohm.m RES<br />
PADS NESW NESW VIEW BUTTONS IMAGE (N-E-S-W-N) XPADS NESW NESW RES<br />
ROM1 ROMI #1 - FAST RAW VOLTAGE ROMI1 INP<br />
ROM2 ROMI #2 - FAST RAW VOLTAGE ROMI2 INP<br />
ROM3 ROMI #3 - FAST RAW VOLTAGE ROMI3 INP<br />
ROM4 ROMI #4 - FAST RAW VOLTAGE ROMI4 INP<br />
ROM5 ROMI #5 - FAST RAW VOLTAGE ROMI5 INP<br />
ROM6 ROMI #6 - FAST RAW VOLTAGE ROMI6 INP<br />
F4B1 SED PAD #4, PROFILE 1 (FAST) F4B1 RES<br />
XRAZ XRMI AZIMUTH EMIAZ INP<br />
DMIN IN MM XRMI MINIMUM CALIPER PAIR DMIN in mm RES<br />
XRAZ XRMI AZIMUTH EMIAZ INP<br />
AHV FT3 M3 ANNULAR HOLE VOLUME MARK AHV ft3 m3 RES<br />
EDD1 OHMM OHMM PAD #1 RESISTIVITY (FAST) EDD1 ohm.m ohm.m RES<br />
C36 IN MM XRMI CALIPER PAIR 3-6 C36 in mm RES<br />
C25 IN MM XRMI CALIPER PAIR 2-5 C25 in mm RES<br />
C14 IN MM XRMI CALIPER PAIR 1-4 C14 in mm RES<br />
BHVT FT3 M3 BOREHOLE VOLUME TOTAL BHVT ft3 m3 RES<br />
BHV FT3 M3 BOREHOLE VOLUME MARK BHV ft3 m3 RES<br />
CAL2 IN MM XRMI CALIPER ARM #2 (DIAMETER) CAL2 in mm RES<br />
AHVT FT3 M3 ANNULAR HOLE VOLUME TOTAL AHVT ft3 m3 RES<br />
CAL3 IN MM XRMI CALIPER ARM #3 (DIAMETER) CAL3 in mm RES<br />
ACZU G G ACCELEROMETER Z UNFILTERED ACZU G G INP<br />
ACYU G G ACCELEROMETER Y UNFILTERED ACYU G G INP<br />
ACXU G G ACCELEROMETER X UNFILTERED ACXU G G INP<br />
ACCZ G G ACCELEROMETER Z-AXIS ACCZ G G RES<br />
9-42 Mnemonics<br />
Type_<br />
Data
Serv_Name<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
XRMI/XROMI - EXT RANGE<br />
MICRO IMAGING<br />
LIS<br />
Mnem<br />
LISU_<br />
eng<br />
LISU_<br />
met Description Mnem<br />
DLISU_<br />
Eng<br />
DLISU_<br />
Met<br />
ACCY G G ACCELEROMETER Y-AXIS ACCY G G RES<br />
ACCX G G ACCELEROMETER X-AXIS ACCX G G RES<br />
ACCQ ACCELEROMETER SUM OF SQUARES ACCQ RES<br />
AZI1 DEG DEG PAD #1 AZIMUTH AZI1 deg deg RES<br />
DXTM 08.3MS 08.3MS Z ACCELEROMETER (FAST) TIME-MS DXTM 8.3 mS 8.3 mS RES<br />
F2B1 SED PAD #2, PROFILE 1 (FAST) F2B1 RES<br />
F1B1 SED PAD #1, PROFILE 1 (FAST) F1B1 RES<br />
EMIM XRMI LAST TOOL COMMAND EMIM INP<br />
EDD6 OHMM OHMM PAD #6 RESISTIVITY (FAST) EDD6 ohm.m ohm.m RES<br />
EDD5 OHMM OHMM PAD #5 RESISTIVITY (FAST) EDD5 ohm.m ohm.m RES<br />
EDD4 OHMM OHMM PAD #4 RESISTIVITY (FAST) EDD4 ohm.m ohm.m RES<br />
CAL1 IN MM XRMI CALIPER ARM #1 (DIAMETER) CAL1 in mm RES<br />
EDD2 OHMM OHMM PAD #2 RESISTIVITY (FAST) EDD2 ohm.m ohm.m RES<br />
F3B1 SED PAD #3, PROFILE 1 (FAST) F3B1 RES<br />
DMAX IN MM XRMI MAXIMUM CALIPER PAIR DMAX in mm RES<br />
DEVI DEG DEG DRIFT ANGLE DEVI deg deg RES<br />
DCAL IN MM XRMI DIFFERENTIAL CALIPER DCAL in mm RES<br />
CALA IN MM XRMI AVERAGE CALIPER CALA in mm RES<br />
CAL6 IN MM XRMI CALIPER ARM #6 (DIAMETER) CAL6 in mm RES<br />
CAL5 IN MM XRMI CALIPER ARM #5 (DIAMETER) CAL5 in mm RES<br />
CAL4 IN MM XRMI CALIPER ARM #4 (DIAMETER) CAL4 in mm RES<br />
EDD3 OHMM OHMM PAD #3 RESISTIVITY (FAST) EDD3 ohm.m ohm.m RES<br />
Mnemonics 9-43<br />
Type_<br />
Data
Log Header Mnemonics<br />
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR LRU5 LOGGING DATA-GENERAL-RUN NO. 5 Character<br />
LOG_HDR LSC1 LOGGING DATA-ACOUSTIC-SCALE R 1 Character<br />
LOG_HDR LSC2 LOGGING DATA-ACOUSTIC-SCALE R 2 Character<br />
LOG_HDR LSC3 LOGGING DATA-ACOUSTIC-SCALE R 3 Character<br />
LOG_HDR LSC4 LOGGING DATA-ACOUSTIC-SCALE R 4 Character<br />
LOG_HDR LSC5 LOGGING DATA-ACOUSTIC-SCALE R 5 Character<br />
LOG_HDR LSL1 LOGGING DATA-NEUTRON-SCALE L 1 Character<br />
LOG_HDR LSL2 LOGGING DATA-NEUTRON-SCALE L 2 Character<br />
LOG_HDR LSL3 LOGGING DATA-NEUTRON-SCALE L 3 Character<br />
LOG_HDR LSL4 LOGGING DATA-NEUTRON-SCALE L 4 Character<br />
LOG_HDR LSL5 LOGGING DATA-NEUTRON-SCALE L 5 Character<br />
LOG_HDR LSP1 LOGGING DATA-GENERAL-SPEED 1 Character<br />
LOG_HDR LSP2 LOGGING DATA-GENERAL-SPEED 2 Character<br />
LOG_HDR LSP3 LOGGING DATA-GENERAL-SPEED 3 Character<br />
LOG_HDR LSP4 LOGGING DATA-GENERAL-SPEED 4 Character<br />
LOG_HDR LSP5 LOGGING DATA-GENERAL-SPEED 5 Character<br />
LOG_HDR LSR1 LOGGING DATA-NEUTRON-SCALE R 1 Character<br />
LOG_HDR LSR2 LOGGING DATA-NEUTRON-SCALE R 2 Character<br />
LOG_HDR LSR3 LOGGING DATA-NEUTRON-SCALE R 3 Character<br />
LOG_HDR LSR4 LOGGING DATA-NEUTRON-SCALE R 4 Character<br />
LOG_HDR LSR5 LOGGING DATA-NEUTRON-SCALE R 5 Character<br />
LOG_HDR LSRV LSRV NAME OF SERVICE Character<br />
LOG_HDR LTO1 LOGGING DATA-GENERAL-DEPTH TO 1 Character<br />
LOG_HDR LTO2 LOGGING DATA-GENERAL-DEPTH TO 2 Character<br />
LOG_HDR LTO3 LOGGING DATA-GENERAL-DEPTH TO 3 Character<br />
LOG_HDR LTO4 LOGGING DATA-GENERAL-DEPTH TO 4 Character<br />
LOG_HDR LTO5 LOGGING DATA-GENERAL-DEPTH TO 5 Character<br />
LOG_HDR LTYP LTYP LOG TYPE Character<br />
LOG_HDR LUL LUL1 LOGGING UNIT LOCATION Character<br />
LOG_HDR LUL2 LUL2 LOGGING UNIT LOCATION 2 Character<br />
LOG_HDR LUL3 LUL3 LOGGING UNIT LOCATION 3 Character<br />
LOG_HDR LUL4 LUL4 LOGGING UNIT LOCATION 4 Character<br />
LOG_HDR LUN LUN1 LOGGING UNIT NUMBER Character<br />
LOG_HDR LUN2 LUN2 LOGGING UNIT NUMBER 2 Character<br />
LOG_HDR LUN3 LUN3 LOGGING UNIT NUMBER 3 Character<br />
LOG_HDR LUN4 LUN4 LOGGING UNIT NUMBER 4 Character<br />
LOG_HDR MCS2 MCS2 MUD CAKE SAMPLE SOURCE 2 Character<br />
LOG_HDR MCS3 MCS3 MUD CAKE SAMPLE SOURCE 3 Character<br />
LOG_HDR MCS4 MCS4 MUD CAKE SAMPLE SOURCE 4 Character<br />
LOG_HDR MCSS MCSS MUD CAKE SAMPLE SOURCE Character<br />
LOG_HDR MCST TMC1 MUDCAKE SAMPLE TEMPERATURE Character<br />
LOG_HDR MCT2 TMC2 MUDCAKE SAMPLE TEMPERATURE 2 Character<br />
LOG_HDR MCT3 TMC3 MUDCAKE SAMPLE TEMPERATURE 3 Character<br />
LOG_HDR MCT4 TMC4 MUDCAKE SAMPLE TEMPERATURE 4 Character<br />
LOG_HDR MFS2 MFSS2 MUD FILTRATE SAMPLE SOURCE 2 Character<br />
LOG_HDR MFS3 MFSS3 MUD FILTRATE SAMPLE SOURCE 3 Character<br />
9-44 Mnemonics
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR MFS4 MFSS4 MUD FILTRATE SAMPLE SOURCE 4 Character<br />
LOG_HDR MFSS MFSS MUD FILTRATE SAMPLE SOURCE Character<br />
LOG_HDR MFST TMF1 MUD FILTRATE SAMPLE TEMPERATURE Character<br />
LOG_HDR MFT2 TMF2 MUD FILTRATE SAMPLE TEMPERATURE 2 Character<br />
LOG_HDR MFT3 TMF3 MUD FILTRATE SAMPLE TEMPERATURE 3 Character<br />
LOG_HDR MFT4 TMF4 MUD FILTRATE SAMPLE TEMPERATURE 4 Character<br />
LOG_HDR MRT MRT MAXIMUM RECORDED TEMPERATURE Character<br />
LOG_HDR MRT2 MRT2 MAXIMUM RECORDED TEMPERATURE 2 Character<br />
LOG_HDR MRT3 MRT3 MAXIMUM RECORDED TEMPERATURE 3 Character<br />
LOG_HDR MRT4 MRT4 MAXIMUM RECORDED TEMPERATURE 4 Character<br />
LOG_HDR MSS MSS SOURCE OF MUD SAMPLE Character<br />
LOG_HDR MSS2 MSS2 SOURCE OF MUD SAMPLE 2 Character<br />
LOG_HDR MSS3 MSS3 SOURCE OF MUD SAMPLE 3 Character<br />
LOG_HDR MSS4 MSS4 SOURCE OF MUD SAMPLE 4 Character<br />
LOG_HDR OS1 OS1 OTHER SERVICES LINE 1 Character<br />
LOG_HDR OS2 OS2 OTHER SERVICES LINE 2 Character<br />
LOG_HDR OS3 OS3 OTHER SERVICES LINE 3 Character<br />
LOG_HDR OS4 OS4 OTHER SERVICES LINE 4 Character<br />
LOG_HDR OS5 OTHER SERVICES LINE 5 Character<br />
LOG_HDR OS6 OTHER SERVICES LINE 6 Character<br />
LOG_HDR OTH1 RES. EQUIP DATA: OTHER 1 (OH) Character<br />
LOG_HDR OTH2 RES. EQUIP DATA: OTHER 2 (OH) Character<br />
LOG_HDR OTH3 RES. EQUIP DATA: OTHER 3 (OH) Character<br />
LOG_HDR OTH4 RES. EQUIP DATA: OTHER 4 (OH) Character<br />
LOG_HDR OTH5 RES. EQUIP DATA: OTHER 5 (OH) Character<br />
LOG_HDR OTH6 RES. EQUIP DATA: OTHER 6 (OH) Character<br />
LOG_HDR PDAT PDAT PERMANENT DATUM Character<br />
LOG_HDR PGMV PROGRAM VERSION Character<br />
LOG_HDR PT1 RES. EQUIP DATA: PAD TYPE 1 (OH) Character<br />
LOG_HDR PT2 RES. EQUIP DATA: PAD TYPE 2 (OH) Character<br />
LOG_HDR PT3 RES. EQUIP DATA: PAD TYPE 3 (OH) Character<br />
LOG_HDR PT4 RES. EQUIP DATA: PAD TYPE 4 (OH) Character<br />
LOG_HDR PT5 RES. EQUIP DATA: PAD TYPE 5 (OH) Character<br />
LOG_HDR PT6 RES. EQUIP DATA: PAD TYPE 6 (OH) Character<br />
LOG_HDR R1 RMK1 REMARKS LINE 1 Character<br />
LOG_HDR R10 REMARKS LINE 10 Character<br />
LOG_HDR R11 REMARKS LINE 11 Character<br />
LOG_HDR R12 REMARKS LINE 12 Character<br />
LOG_HDR R2 RMK2 REMARKS LINE 2 Character<br />
LOG_HDR R3 RMK3 REMARKS LINE 3 Character<br />
LOG_HDR R4 RMK4 REMARKS LINE 4 Character<br />
LOG_HDR R5 REMARKS LINE 5 Character<br />
LOG_HDR R6 REMARKS LINE 6 Character<br />
LOG_HDR R7 REMARKS LINE 7 Character<br />
LOG_HDR R8 REMARKS LINE 8 Character<br />
LOG_HDR ACB ADD. SAMPLES: RMC - BHT 1 (OH) Character<br />
LOG_HDR ACB2 ADD. SAMPLES: RMC - BHT 2 (OH) Character<br />
LOG_HDR ACT ADD. SAMPLES: MUDCAKE TEMP. 1 Character<br />
LOG_HDR ACT2 ADD. SAMPLES: MUDCAKE TEMP. 2 Character<br />
Mnemonics 9-45
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR ACX ADD. SAMPLES: RMC BOTTOMHOLE TEMP Character<br />
LOG_HDR ACX2 ADD. SAMPLES: RMC BOTTOMHOLE TEMP Character<br />
LOG_HDR ADD ADDITIONAL SAMPLES: DEPTH-DRILLER 1 (OH) Character<br />
LOG_HDR ADD2 ADDITIONAL SAMPLES: DEPTH-DRILLER 2 (OH) Character<br />
LOG_HDR ADE ADDITIONAL SAMPLES: DENSITY 1 Character<br />
LOG_HDR ADE2 ADDITIONAL SAMPLES: DENSITY 2 Character<br />
LOG_HDR ADFT ADDITIONAL SAMPLES: FLUID TYPE IN HOLE 1 (OH) Character<br />
LOG_HDR ADT ADDITIONAL SAMPLES: DATE 1 (OPEN HOLE ) Character<br />
LOG_HDR ADT2 ADDITIONAL SAMPLES: DATE 1 (OPEN HOLE ) Character<br />
LOG_HDR AFB ADD. SAMPLES: RMF - BHT 1 (OH) Character<br />
LOG_HDR AFB2 ADD. SAMPLES: RMF - BHT 2 (OH) Character<br />
LOG_HDR AFL ADDITIONAL SAMPLES: FLUID LOSS 1 Character<br />
LOG_HDR AFL2 ADDITIONAL SAMPLES: FLUID LOSS 2 Character<br />
LOG_HDR AFT ADD. SAMPLES: MUD FILTRATE TEMP 1 (OH) Character<br />
LOG_HDR AFT2 ADD. SAMPLES: MUD FILTRATE TEMP 2 (OH) Character<br />
LOG_HDR AFX ADD. SAMPLES: RMF BOTTOMHOLE TEMP 1 (OH) Character<br />
LOG_HDR AFX2 ADD. SAMPLES: RMF BOTTOMHOLE TEMP 2 (OH) Character<br />
LOG_HDR AMS2 ADD. SAMPLES: MUD SAMPLE TEMP 2 (OH) Character<br />
LOG_HDR AMST ADD. SAMPLES: MUD SAMPLE TEMP 1 (OH) Character<br />
LOG_HDR APD APD ABOVE PERMANENT DATUM Character<br />
LOG_HDR APH ADDITIONAL SAMPLES: PH 1 (OH) Character<br />
LOG_HDR APH2 ADDITIONAL SAMPLES: PH 2 (OH) Character<br />
LOG_HDR ARB ADD. SAMPLES: RES. OF MUD - BHT 1 (OH) Character<br />
LOG_HDR ARB2 ADD. SAMPLES: RES. OF MUD - BHT 2 (OH) Character<br />
LOG_HDR ARC ADD. SAMPLES: RES. OF MUDCAKE 1 (OH) Character<br />
LOG_HDR ARC2 ADD. SAMPLES: RES. OF MUDCAKE 2 (OH) Character<br />
LOG_HDR ARF ADD. SAMPLES: RES. MUD FILTRATE 1 (OH) Character<br />
LOG_HDR ARF2 ADD. SAMPLES: RES. MUD FILTRATE 2 (OH) Character<br />
LOG_HDR ARM ADD. SAMPLES: RES. OF MUD SAMPLE 1 (OH) Character<br />
LOG_HDR ARM2 ADD. SAMPLES: RES. OF MUD SAMPLE 2 (OH) Character<br />
LOG_HDR ARX ADD. SAMPLES: RM BOTTOMHOLE TEMP 1 (OH) Character<br />
LOG_HDR ARX2 ADD. SAMPLES: RM BOTTOMHOLE TEMP 2 (OH) Character<br />
LOG_HDR ASC ADD. SAMPLES: SOURCE RMC 1 (OH) Character<br />
LOG_HDR ASC2 ADD. SAMPLES: SOURCE RMC 2 (OH) Character<br />
LOG_HDR ASF ADD. SAMPLES: SOURCE RMF 1 (OH) Character<br />
LOG_HDR ASF2 ADD. SAMPLES: SOURCE RMF 2 (OH) Character<br />
LOG_HDR ASN ADDITIONAL SAMPLES: SAMPLE NO. 1 (OH) Character<br />
LOG_HDR ASN2 ADDITIONAL SAMPLES: SAMPLE NO. 2 (OH) Character<br />
LOG_HDR ASS ADD. SAMPLES: SOURCE OF SAMPLE 1 (OH) Character<br />
LOG_HDR ASS2 ADD. SAMPLES: SOURCE OF SAMPLE 2 (OH) Character<br />
LOG_HDR AST2 ADD. SAMPLES: MUD FILTRATE TEMP 2 (OH) Character<br />
LOG_HDR AV ADDITIONAL SAMPLES: VISCOSITY 1 (OH) Character<br />
LOG_HDR AV2 ADDITIONAL SAMPLES: VISCOSITY 2 (OH) Character<br />
LOG_HDR EGL EGL ELEVATION OF GROUND LEVEL Character<br />
LOG_HDR BARI BARI BARITE CORRECTION Character<br />
LOG_HDR R9 REMARKS LINE 9 Character<br />
LOG_HDR RIG DRILLING RIG Character<br />
LOG_HDR RMB RMBH1 RESISTIVITY OF MUD - BHT Character<br />
LOG_HDR RMB2 RMBH2 RESISTIVITY OF MUD - BHT 2 Character<br />
9-46 Mnemonics
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR RMB3 RMBH3 RESISTIVITY OF MUD - BHT 3 Character<br />
LOG_HDR RMB4 RMBH4 RESISTIVITY OF MUD - BHT 4 Character<br />
LOG_HDR RMC2 RMC2 RESISTIVITY OF MUD CAKE SAMPLE 2 Character<br />
LOG_HDR RMC3 RMC3 RESISTIVITY OF MUD CAKE SAMPLE 3 Character<br />
LOG_HDR RMC4 RMC4 RESISTIVITY OF MUD CAKE SAMPLE 4 Character<br />
LOG_HDR RMCS RMCS RESISTIVITY OF MUD CAKE SAMPLE Character<br />
LOG_HDR RMF2 RMF2 RESISTIVITY OF MUD FILTRATE SAMPLE 2 Character<br />
LOG_HDR RMF3 RMF3 RESISTIVITY OF MUD FILTRATE SAMPLE 3 Character<br />
LOG_HDR RMF4 RMF4 RESISTIVITY OF MUD FILTRATE SAMPLE 4 Character<br />
LOG_HDR RMFS RMF1 RESISTIVITY OF MUD FILTRATE SAMPLE Character<br />
LOG_HDR RMS RM1 RESISTIVITY OF MUD SAMPLE Character<br />
LOG_HDR RMS2 RM2 RESISTIVITY OF MUD SAMPLE 2 Character<br />
LOG_HDR RMS3 RM3 RESISTIVITY OF MUD SAMPLE 3 Character<br />
LOG_HDR RMS4 RM4 RESISTIVITY OF MUD SAMPLE 4 Character<br />
LOG_HDR RRN1 RES. EQUIP DATA: RUN NO 1 (OH) Character<br />
LOG_HDR RRN2 RES. EQUIP DATA: RUN NO 2 (OH) Character<br />
LOG_HDR RRN3 RES. EQUIP DATA: RUN NO 3 (OH) Character<br />
LOG_HDR RRN4 RES. EQUIP DATA: RUN NO 4 (OH) Character<br />
LOG_HDR RRN5 RES. EQUIP DATA: RUN NO 5 (OH) Character<br />
LOG_HDR RRN6 RES. EQUIP DATA: RUN NO 6 (OH) Character<br />
LOG_HDR RUN RUN NUMBER Character<br />
LOG_HDR RUN2 RUN NUMBER 2 Character<br />
LOG_HDR RUN3 RUN NUMBER 3 Character<br />
LOG_HDR RUN4 RUN NUMBER 4 Character<br />
LOG_HDR SDC1 RES. SCALE CHANGES: DEPTH 1 (OH) Character<br />
LOG_HDR SDC2 RES. SCALE CHANGES: DEPTH 2 (OH) Character<br />
LOG_HDR SDC3 RES. SCALE CHANGES: DEPTH 3 (OH) Character<br />
LOG_HDR SDC4 RES. SCALE CHANGES: DEPTH 4 (OH) Character<br />
LOG_HDR SDC5 RES. SCALE CHANGES: DEPTH 5 (OH) Character<br />
LOG_HDR SCT1 RES. SCALE CHANGES: TYPE LOG 1 (OH) Character<br />
LOG_HDR SCT2 RES. SCALE CHANGES: TYPE LOG 2 (OH) Character<br />
LOG_HDR SCT3 RES. SCALE CHANGES: TYPE LOG 3 (OH) Character<br />
LOG_HDR SCT4 RES. SCALE CHANGES: TYPE LOG 4 (OH) Character<br />
LOG_HDR SCT5 RES. SCALE CHANGES: TYPE LOG 5 (OH) Character<br />
LOG_HDR SDAT DATLOG DATE SECTION STARTED Character<br />
LOG_HDR SDH1 RES. SCALE CHANGES: SCALE DOWN HOLE 1 Character<br />
LOG_HDR SDH2 RES. SCALE CHANGES: SCALE DOWN HOLE 2 Character<br />
LOG_HDR SDH3 RES. SCALE CHANGES: SCALE DOWN HOLE 3 Character<br />
LOG_HDR SDH4 RES. SCALE CHANGES: SCALE DOWN HOLE 4 Character<br />
LOG_HDR SDH5 RES. SCALE CHANGES: SCALE DOWN HOLE 5 Character<br />
LOG_HDR SON SON1 SERVICE/TICKET ORDER NUMBER Character<br />
LOG_HDR STAT STATE STATE Character<br />
LOG_HDR STEM STEM SURFACE TEMP Character<br />
LOG_HDR STIM TIMLOG TIME SECTION STARTED Character<br />
LOG_HDR SUH1 RES. SCALE CHANGES: SCALE UP HOLE 1 (OH) Character<br />
LOG_HDR SUH2 RES. SCALE CHANGES: SCALE UP HOLE 2 (OH) Character<br />
LOG_HDR SUH3 RES. SCALE CHANGES: SCALE UP HOLE 3 (OH) Character<br />
LOG_HDR SUH4 RES. SCALE CHANGES: SCALE UP HOLE 4 (OH) Character<br />
LOG_HDR SUH5 RES. SCALE CHANGES: SCALE UP HOLE 5 (OH) Character<br />
Mnemonics 9-47
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR TCS TCS TIME CIRCULATION STOPPED Character<br />
LOG_HDR TCS2 TCS2 TIME CIRCULATION STOPPED 2 Character<br />
LOG_HDR TCS3 TCS3 TIME CIRCULATION STOPPED 3 Character<br />
LOG_HDR TCS4 TCS4 TIME CIRCULATION STOPPED 4 Character<br />
LOG_HDR TDD1 TDD1 DRILLERS DEPTH 1 Character<br />
LOG_HDR TDD2 TDD2 DRILLERS DEPTH 2 Character<br />
LOG_HDR TDD3 TDD3 DRILLERS DEPTH 3 Character<br />
LOG_HDR TDD4 TDD4 DRILLERS DEPTH 4 Character<br />
LOG_HDR TDL TDL LOGGERS DEPTH Character<br />
LOG_HDR TDL2 TDL2 LOGGERS DEPTH 2 Character<br />
LOG_HDR TDL3 TDL3 LOGGERS DEPTH 3 Character<br />
LOG_HDR TDL4 TDL4 LOGGERS DEPTH 4 Character<br />
LOG_HDR TLA2 TLAB2 TIME LOGGING ON BOTTOM 2 Character<br />
LOG_HDR TLA3 TLAB3 TIME LOGGING ON BOTTOM 3 Character<br />
LOG_HDR TLA4 TLAB4 TIME LOGGING ON BOTTOM 4 Character<br />
LOG_HDR TLAB TLAB TIME LOGGING ON BOTTOM Character<br />
LOG_HDR TLI TLI TOP LOGGED INTERVAL Character<br />
LOG_HDR TLI2 TLI2 TOP LOGGED INTERVAL 2 Character<br />
LOG_HDR TLI3 TLI3 TOP LOGGED INTERVAL 3 Character<br />
LOG_HDR TLI4 TL4 TOP LOGGED INTERVAL 4 Character<br />
LOG_HDR TN1 RES. EQUIP DATA: TOOL TYPE & NO. 1 (OH) Character<br />
LOG_HDR TN2 RES. EQUIP DATA: TOOL TYPE & NO. 2 (OH) Character<br />
LOG_HDR TN3 RES. EQUIP DATA: TOOL TYPE & NO. 3 (OH) Character<br />
LOG_HDR TN4 RES. EQUIP DATA: TOOL TYPE & NO. 4 (OH) Character<br />
LOG_HDR TN5 RES. EQUIP DATA: TOOL TYPE & NO. 5 (OH) Character<br />
LOG_HDR TN6 RES. EQUIP DATA: TOOL TYPE & NO. 6 (OH) Character<br />
LOG_HDR TOOL TOOL TOOL STRING Character<br />
LOG_HDR TPS1 RES. EQUIP DATA: TOOL POS. 1 (OH) Character<br />
LOG_HDR TPS2 RES. EQUIP DATA: TOOL POS. 2 (OH) Character<br />
LOG_HDR TPS3 RES. EQUIP DATA: TOOL POS. 3 (OH) Character<br />
LOG_HDR TPS4 RES. EQUIP DATA: TOOL POS. 4 (OH) Character<br />
LOG_HDR TPS5 RES. EQUIP DATA: TOOL POS. 5 (OH) Character<br />
LOG_HDR TPS6 RES. EQUIP DATA: TOOL POS. 6 (OH) Character<br />
LOG_HDR TTL1 HEADER TITLE LINE 1 Character<br />
LOG_HDR TTL4 HEADER TITLE LINE 4 Character<br />
LOG_HDR WIT2 WITN2 WITNESS 2 NAME Character<br />
LOG_HDR WIT3 WITN3 WITNESS 3 NAME Character<br />
LOG_HDR BASI BASI BASIN Character<br />
LOG_HDR BHT BHT BOTTOMHOLE TEMPERATURE Character<br />
LOG_HDR BHT2 BHT2 BOTTOMHOLE TEMPERATURE 2 Character<br />
LOG_HDR BHT3 BHT3 BOTTOMHOLE TEMPERATURE 3 Character<br />
LOG_HDR BHT4 BHT4 BOTTOMHOLE TEMPERATURE 4 Character<br />
LOG_HDR BLI BLI1 BOTTOM LOGGED INTERVAL Character<br />
LOG_HDR BLI2 BLI2 BOTTOM LOGGED INTERVAL 2 Character<br />
LOG_HDR BLI3 BLI3 BOTTOM LOGGED INTERVAL 3 Character<br />
LOG_HDR BLI4 BLI4 BOTTOM LOGGED INTERVAL 4 Character<br />
LOG_HDR BS1 BITDI1 BIT SIZE 1 Character<br />
LOG_HDR BS2 BITDI2 BIT SIZE 2 Character<br />
LOG_HDR BS3 BITDI3 BIT SIZE 3 Character<br />
9-48 Mnemonics
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR BS4 BITDI4 BIT SIZE 4 Character<br />
LOG_HDR CBD1 DEDRI1 CASING BOTTOM DRILLER 1 Character<br />
LOG_HDR CBD2 DEDRI2 CASING BOTTOM DRILLER 2 Character<br />
LOG_HDR CBD3 DEDRI3 CASING BOTTOM DRILLER 3 Character<br />
LOG_HDR CBD4 DEDRI4 CASING BOTTOM DRILLER 4 Character<br />
LOG_HDR CBL1 DELOG1 CASING BOTTOM LOGGER 1 Character<br />
LOG_HDR CBL2 DELOG2 CASING BOTTOM LOGGER 2 Character<br />
LOG_HDR CBL3 DELOG3 CASING BOTTOM LOGGER 3 Character<br />
LOG_HDR CBL4 DELOG4 CASING BOTTOM LOGGER 4 Character<br />
LOG_HDR CN COMPAN COMPANY NAME Character<br />
LOG_HDR COUN COUNTY COUNTY Character<br />
LOG_HDR CS1 CASDI1 CASING DIAMETER 1 Character<br />
LOG_HDR CS2 CASDI2 CASING DIAMETER 2 Character<br />
LOG_HDR CS3 CASDI3 CASING DIAMETER 3 Character<br />
LOG_HDR CS4 CASDI4 CASING DIAMETER 4 Character<br />
LOG_HDR CSW1 CASWE1 CASING WEIGHT 1 Character<br />
LOG_HDR CSW2 CASWE2 CASING WEIGHT 2 Character<br />
LOG_HDR CSW3 CASWE3 CASING WEIGHT 3 Character<br />
LOG_HDR CSW4 CASWE4 CASING WEIGHT 4 Character<br />
LOG_HDR CTRY COUNTR COUNTRY Character<br />
LOG_HDR DAT2 HDATE2 LOGGING DATE 2 Character<br />
LOG_HDR DAT3 HDATE3 LOGGING DATE 3 Character<br />
LOG_HDR DAT4 HDATE4 LOGGING DATE 4 Character<br />
LOG_HDR DDEG DIRECTIONAL DEPTH Character<br />
LOG_HDR DDEV DIRECTIONAL DEVIATION Character<br />
LOG_HDR DFD DFD DRILLING FLUID DENSITY Character<br />
LOG_HDR DFD2 DFD2 DRILLING FLUID DENSITY 2 Character<br />
LOG_HDR DFD3 DFD3 DRILLING FLUID DENSITY 3 Character<br />
LOG_HDR DFD4 DFD4 DRILLING FLUID DENSITY 4 Character<br />
LOG_HDR DFL DFL DRILLING FLUID LOSS Character<br />
LOG_HDR DFL2 DFL2 DRILLING FLUID LOSS 2 Character<br />
LOG_HDR DFL3 DFL3 DRILLING FLUID LOSS 3 Character<br />
LOG_HDR DFL4 DFL4 DRILLING FLUID LOSS 4 Character<br />
LOG_HDR DFP2 DFPH2 DRILLING FLUID PH 2 Character<br />
LOG_HDR DFP3 DFPH3 DRILLING FLUID PH 3 Character<br />
LOG_HDR DFP4 DFPH4 DRILLING FLUID PH 4 Character<br />
LOG_HDR DFPH DFPH DRILLING FLUID PH Character<br />
LOG_HDR DFS DFS SALINITY Character<br />
LOG_HDR DFT DFT DRILLING FLUID TYPE Character<br />
LOG_HDR DFT2 DFT2 DRILLING FLUID TYPE 2 Character<br />
LOG_HDR DFT3 DFT3 DRILLING FLUID TYPE 3 Character<br />
LOG_HDR DFT4 DFT4 DRILLING FLUID TYPE 4 Character<br />
LOG_HDR DFV DFV DRILLING FLUID VISCOSITY Character<br />
LOG_HDR DFV2 DFV2 DRILLING FLUID VISCOSITY 2 Character<br />
LOG_HDR DFV3 DFV3 DRILLING FLUID VISCOSITY 3 Character<br />
LOG_HDR DFV4 DFV4 DRILLING FLUID VISCOSITY 4 Character<br />
LOG_HDR DKOP DIRECTIONAL KOP Character<br />
LOG_HDR DMF DMF DRILLING MEASURED Character<br />
LOG_HDR DRMK DIRECTIONAL REMARKS Character<br />
Mnemonics 9-49
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR EAER EQUIP. DATA-ACOUSTIC-SERIAL NO. Character<br />
LOG_HDR EAOD EQUIP. DATA-ACOUSTIC-MODEL NO. Character<br />
LOG_HDR ECNT EQUIP. DATA-ACOUSTIC-NO. OF CENT Character<br />
LOG_HDR EDF HIGHT3 ELEVATION OF DRILLING FLOOR Character<br />
LOG_HDR EDIA EQUIP. DATA-DENSITY-DIAMETER Character<br />
LOG_HDR EDOD EQUIP. DATA-DENSITY-MODEL NO. Character<br />
LOG_HDR EDS1 EQUIP. DATA-GAMMA-DISTANCE TO SOURCE Character<br />
LOG_HDR EDSN EQUIP. DATA-DENSITY-SOURCE SERIAL NO. Character<br />
LOG_HDR ELT EQUIP. DATA-GAMMA-DETECTOR MODEL NO. Character<br />
LOG_HDR EDTR EQUIP. DATA-DENSITY-STRENGTH Character<br />
LOG_HDR EDUN EQUIP. DATA-DENSITY-RUN NO. Character<br />
LOG_HDR EFWD EQUIP. DATA-ACOUSTIC-FWDA Character<br />
LOG_HDR EGMD EQUIP. DATA-GAMMA-MODEL NO. Character<br />
LOG_HDR EGRN EQUIP. DATA-GAMMA-RUN NO. Character<br />
LOG_HDR EGSN EQUIP. DATA-GAMMA-SERIAL NO. Character<br />
LOG_HDR EKB HIGHT1 ELEVATION OF KELLY BUSHING Character<br />
LOG_HDR ELGT EQUIP. DATA-DENSITY-LOG TYPE Character<br />
LOG_HDR ELN1 EQUIP. DATA-GAMMA-LENGTH Character<br />
LOG_HDR EMIA EQUIP. DATA-GAMMA-DIAMETER Character<br />
LOG_HDR ENER EQUIP. DATA-DENSITY-SERIAL NO. Character<br />
LOG_HDR ENG2 ENGI2 ENGINEER 2 NAME Character<br />
LOG_HDR ENG3 ENGI3 ENGINEER 3 NAME Character<br />
LOG_HDR ENG4 ENGI4 ENGINEER 4 NAME Character<br />
LOG_HDR ENGI ENGI1 ENGINEER 1 NAME Character<br />
LOG_HDR ENGT EQUIP. DATA-NEUTRON-LOG TYPE Character<br />
LOG_HDR ENIA EQUIP. DATA-NEUTRON-DIAMETER Character<br />
LOG_HDR ENOD EQUIP. DATA-NEUTRON-MODEL NO. Character<br />
LOG_HDR EPD EPD ELEVATATION OF PERMANENT DATUM Character<br />
LOG_HDR EQLA EQUIP. DATA-ACOUSTIC-LSA Character<br />
LOG_HDR ERUN EQUIP. DATA-ACOUSTIC-RUN NO. Character<br />
LOG_HDR ESAT EQUIP. DATA-DENSITY-SOURCE TYPE Character<br />
LOG_HDR ESER EQUIP. DATA-NEUTRON-SERIAL NO. Character<br />
LOG_HDR ESPC EQUIP. DATA-ACOUSTIC-SPACING Character<br />
LOG_HDR ESRT EQUIP. DATA-NEUTRON-SOURCE TYPE Character<br />
LOG_HDR ESSN EQUIP. DATA-NEUTRON-SOURCE SERIAL NO. Character<br />
LOG_HDR ESTR EQUIP. DATA-NEUTRON-STRENGTH Character<br />
LOG_HDR ETP1 EQUIP. DATA-GAMMA-TYPE Character<br />
LOG_HDR EURN EQUIP. DATA-NEUTRON-RUN NO. Character<br />
LOG_HDR FL1 LOC1 FIELD LOCATION LINE 1 Character<br />
LOG_HDR FN FIELD FIELD NAME Character<br />
LOG_HDR HDAT HDAT DATUM Character<br />
LOG_HDR HDRT HEADER TYPE Character<br />
LOG_HDR LAT LAT LATITUDE Character<br />
LOG_HDR LCC LOGGING COMPANY_CODE Character<br />
LOG_HDR LCL1 LOGGING DATA-GAMMA-SCALE L 1 Character<br />
LOG_HDR LCL2 LOGGING DATA-GAMMA-SCALE L 2 Character<br />
LOG_HDR LCL3 LOGGING DATA-GAMMA-SCALE L 3 Character<br />
LOG_HDR LCL4 LOGGING DATA-GAMMA-SCALE L 4 Character<br />
LOG_HDR LCL5 LOGGING DATA-GAMMA-SCALE L 5 Character<br />
9-50 Mnemonics
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR LCR1 LOGGING DATA-GAMMA-SCALE R 1 Character<br />
LOG_HDR LCR2 LOGGING DATA-GAMMA-SCALE R 2 Character<br />
LOG_HDR LCR3 LOGGING DATA-GAMMA-SCALE R 3 Character<br />
LOG_HDR LCR4 LOGGING DATA-GAMMA-SCALE R 4 Character<br />
LOG_HDR LCR5 LOGGING DATA-GAMMA-SCALE R 5 Character<br />
LOG_HDR LDAT LDAT LOGGING DATE Character<br />
LOG_HDR LDL1 LOGGING DATA-DENSITY-SCALE L 1 Character<br />
LOG_HDR LDL2 LOGGING DATA-DENSITY-SCALE L 2 Character<br />
LOG_HDR LDL3 LOGGING DATA-DENSITY-SCALE L 3 Character<br />
LOG_HDR LDL4 LOGGING DATA-DENSITY-SCALE L 4 Character<br />
LOG_HDR LDL5 LOGGING DATA-DENSITY-SCALE L 5 Character<br />
LOG_HDR LDR1 LOGGING DATA-DENSITY-SCALE R 1 Character<br />
LOG_HDR LDR2 LOGGING DATA-DENSITY-SCALE R 2 Character<br />
LOG_HDR LDR3 LOGGING DATA-DENSITY-SCALE R 3 Character<br />
LOG_HDR LDR4 LOGGING DATA-DENSITY-SCALE R 4 Character<br />
LOG_HDR LDR5 LOGGING DATA-DENSITY-SCALE R 5 Character<br />
LOG_HDR LDX1 LOGGING DATA-DENSITY-MATRIX 1 Character<br />
LOG_HDR LDX2 LOGGING DATA-DENSITY-MATRIX 2 Character<br />
LOG_HDR LDX3 LOGGING DATA-DENSITY-MATRIX 3 Character<br />
LOG_HDR LDX4 LOGGING DATA-DENSITY-MATRIX 4 Character<br />
LOG_HDR LDX5 LOGGING DATA-DENSITY-MATRIX 5 Character<br />
LOG_HDR LFR1 LOGGING DATA-GENERAL-DEPTH FROM 1 Character<br />
LOG_HDR LFR2 LOGGING DATA-GENERAL-DEPTH FROM 2 Character<br />
LOG_HDR LFR3 LOGGING DATA-GENERAL-DEPTH FROM 3 Character<br />
LOG_HDR LFR4 LOGGING DATA-GENERAL-DEPTH FROM 4 Character<br />
LOG_HDR LFR5 LOGGING DATA-GENERAL-DEPTH FROM 5 Character<br />
LOG_HDR LGC1 LOGGING DATA-ACOUSTIC-SCALE L 1 Character<br />
LOG_HDR LGC2 LOGGING DATA-ACOUSTIC-SCALE L 2 Character<br />
LOG_HDR LGC3 LOGGING DATA-ACOUSTIC-SCALE L 3 Character<br />
LOG_HDR LGC4 LOGGING DATA-ACOUSTIC-SCALE L 4 Character<br />
LOG_HDR LGC5 LOGGING DATA-ACOUSTIC-SCALE L 5 Character<br />
LOG_HDR LMF LMF LOG MEASURED FROM Character<br />
LOG_HDR LMT1 LOGGING DATA-ACOUSTIC-MATRIX 1 Character<br />
LOG_HDR LMT2 LOGGING DATA-ACOUSTIC-MATRIX 2 Character<br />
LOG_HDR LMT3 LOGGING DATA-ACOUSTIC-MATRIX 3 Character<br />
LOG_HDR LMT4 LOGGING DATA-ACOUSTIC-MATRIX 4 Character<br />
LOG_HDR LMT5 LOGGING DATA-ACOUSTIC-MATRIX 5 Character<br />
LOG_HDR LMX1 LOGGING DATA-NEUTRON-MATRIX 1 Character<br />
LOG_HDR LMX2 LOGGING DATA-NEUTRON-MATRIX 2 Character<br />
LOG_HDR LMX3 LOGGING DATA-NEUTRON-MATRIX 3 Character<br />
LOG_HDR LMX4 LOGGING DATA-NEUTRON-MATRIX 4 Character<br />
LOG_HDR LMX5 LOGGING DATA-NEUTRON-MATRIX 5 Character<br />
LOG_HDR LNAM LNAM Character<br />
LOG_HDR LONG XLONG LONGITUDE Character<br />
LOG_HDR LRU1 LOGGING DATA-GENERAL-RUN NO. 1 Character<br />
LOG_HDR LRU2 LOGGING DATA-GENERAL-RUN NO. 2 Character<br />
LOG_HDR LRU3 LOGGING DATA-GENERAL-RUN NO. 3 Character<br />
LOG_HDR LRU4 LOGGING DATA-GENERAL-RUN NO. 4 Character<br />
LOG_HDR WIT4 WITN4 WITNESS 4 NAME Character<br />
Mnemonics 9-51
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR WITN WITN1 WITNESS 1 NAME Character<br />
LOG_HDR WN NAMWEL WELL NAME Character<br />
LOG_HDR X X X COORDINATE Character<br />
LOG_HDR XTP MAX. REC TEMP. @ 1 (OPEN HOLE) Character<br />
LOG_HDR XTP2 MAX. REC TEMP. @ 2 (OPEN HOLE) Character<br />
LOG_HDR XTP3 MAX. REC TEMP. @ 3 (OPEN HOLE) Character<br />
LOG_HDR XTP4 MAX. REC TEMP. @ 4 (OPEN HOLE) Character<br />
LOG_HDR Y Y Y COORDINATE Character<br />
LOG_HDR SON ORDER-NUMBER String<br />
LOG_HDR RUN RUN-NUMBER String<br />
LOG_HDR WN WELL-NAME String<br />
LOG_HDR FN FIELD-NAME String<br />
LOG_HDR LCC PRODUCER-CODE String<br />
LOG_HDR CN COMPANY String<br />
LOG_HDR ACB ADD. SAMPLES: RMC - BHT 1 (OH) String<br />
LOG_HDR ACB2 ADD. SAMPLES: RMC - BHT 2 (OH) String<br />
LOG_HDR ACT ADD. SAMPLES: MUDCAKE TEMP. 1 (OH) String<br />
LOG_HDR ACT2 ADD. SAMPLES: MUDCAKE TEMP. 2 (OH) String<br />
LOG_HDR ACX ADD. SAMPLES: RMC OTTOMHOLE TEMP 1 (OH) String<br />
LOG_HDR ACX2 ADD. SAMPLES: RMC OTTOMHOLE TEMP 2 (OH) String<br />
LOG_HDR ADD ADDITIONAL SAMPLES: DEPTH-DRILLER 1 (OH) String<br />
LOG_HDR ADD2 ADDITIONAL SAMPLES: DEPTH-DRILLER 2 (OH) String<br />
LOG_HDR ADE ADDITIONAL SAMPLES: DENSITY 1 (OH) String<br />
LOG_HDR ADE2 ADDITIONAL SAMPLES: DENSITY 2 (OH) String<br />
LOG_HDR ADFT ADDI. SAMPLES: FLUID TYPE IN HOLE 1 (OH) String<br />
LOG_HDR ADT ADDITIONAL SAMPLES: DATE 1 (OPEN HOLE) String<br />
LOG_HDR ADT2 ADDITIONAL SAMPLES: DATE 2 (OPEN HOLE) String<br />
LOG_HDR AFB ADD. SAMPLES: RMF - BHT 1 (OH) String<br />
LOG_HDR AFB2 ADD. SAMPLES: RMF - BHT 2 (OH) String<br />
LOG_HDR AFL ADDITIONAL SAMPLES: FLUID LOSS 1 (OH) String<br />
LOG_HDR AFL2 ADDITIONAL SAMPLES: FLUID LOSS 2 (OH) String<br />
LOG_HDR AFT ADD. SAMPLES: MUD FILTRATE TEMP. 1 (OH) String<br />
LOG_HDR AFT2 ADD. SAMPLES: MUD FILTRATE TEMP. 2 (OH) String<br />
LOG_HDR AFX ADD. SAMPLES: RMF BOTTOMHOLE TEMP 1 (OH) String<br />
LOG_HDR AFX2 ADD. SAMPLES: RMF BOTTOMHOLE TEMP 2 (OH) String<br />
LOG_HDR AMS2 ADD. SAMPLES: MUD SAMPLE TEMP 2 (OH) String<br />
LOG_HDR AMST ADD. SAMPLES: MUD SAMPLE TEMP 1 (OH) String<br />
LOG_HDR APD ABOVE PERMANENT DATUM String<br />
LOG_HDR APH ADDITIONAL SAMPLES: PH 1 (OH) String<br />
LOG_HDR APH2 ADDITIONAL SAMPLES: PH 2 (OH) String<br />
LOG_HDR ARB ADD. SAMPLES: RES. OF MUD - BHT 1 (OH) String<br />
LOG_HDR ARB2 ADD. SAMPLES: RES. OF MUD - BHT 2 (OH) String<br />
LOG_HDR ARC ADD. SAMPLES: RES. OF MUDCAKE 1 (OH) String<br />
LOG_HDR ARC2 ADD. SAMPLES: RES. OF MUDCAKE 2 (OH) String<br />
LOG_HDR ARF ADD. SAMPLES: RES. MUD FILTRATE 1 (OH) String<br />
LOG_HDR ARF2 ADD. SAMPLES: RES. MUD FILTRATE 2 (OH) String<br />
LOG_HDR AR, ADD. SAMPLES: RES. OF MUD SAMPLE 1 (OH) String<br />
LOG_HDR ARM2 ADD. SAMPLES: RES. OF MUD SAMPLE 2 (OH) String<br />
LOG_HDR ARX ADD. SAMPLES: RM BOTTOMHOLE TEMP 1 (OH) String<br />
9-52 Mnemonics
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR ARX2 ADD. SAMPLES: RM BOTTOMHOLE TEMP 2 (OH) String<br />
LOG_HDR ASC ADD. SAMPLES: SOURCE RMC 1 (OH) String<br />
LOG_HDR ASC2 ADD. SAMPLES: SOURCE RMC 2 (OH) String<br />
LOG_HDR ASF ADD. SAMPLES: SOURCE RMF 1 (OH) String<br />
LOG_HDR ASF2 ADD. SAMPLES: SOURCE RMF 2 (OH) String<br />
LOG_HDR ASN ADDITIONAL SAMPLES: SAMPLE NO. 1 (OH) String<br />
LOG_HDR ASN2 ADDITIONAL SAMPLES: SAMPLE NO. 2 (OH) String<br />
LOG_HDR ASS ADD. SAMPLES: SOURCE OF SAMPLE 1 (OH) String<br />
LOG_HDR ASS2 ADD. SAMPLES: SOURCE OF SAMPLE 2 (OH) String<br />
LOG_HDR AST2 ADD. SAMPLES: MUD FILTRATE TEMP. 2 (OH) String<br />
LOG_HDR AV ADDITIONAL SAMPLES: VISCOSITY 1 (OH) String<br />
LOG_HDR AV2 ADDITIONAL SAMPLES: VISCOSITY 2 (OH) String<br />
LOG_HDR EGL EGL ELEVATION OF GROUND LEVEL String<br />
LOG_HDR BARI BARITE CORRECTION String<br />
LOG_HDR BASI BASIN String<br />
LOG_HDR BHT BOTTOMHOLE TEMPERATURE String<br />
LOG_HDR BHT2 BOTTOMHOLE TEMPERATURE 2 String<br />
LOG_HDR BHT3 BOTTOMHOLE TEMPERATURE 3 String<br />
LOG_HDR BHT4 BOTTOMHOLE TEMPERATURE 4 String<br />
LOG_HDR BLI BOTTOM LOGGED INTERVAL String<br />
LOG_HDR BLI2 BOTTOM LOGGED INTERVAL 2 String<br />
LOG_HDR BLI3 BOTTOM LOGGED INTERVAL 3 String<br />
LOG_HDR BLI4 BOTTOM LOGGED INTERVAL 4 String<br />
LOG_HDR BS1 BIT SIZE 1 String<br />
LOG_HDR BS2 BIT SIZE 2 String<br />
LOG_HDR BS3 BIT SIZE 3 String<br />
LOG_HDR BS4 BIT SIZE 4 String<br />
LOG_HDR CBD1 CASING BOTTOM DRILLER 1 String<br />
LOG_HDR CBD2 CASING BOTTOM DRILLER 2 String<br />
LOG_HDR CBD3 CASING BOTTOM DRILLER 3 String<br />
LOG_HDR CBD4 CASING BOTTOM DRILLER 4 String<br />
LOG_HDR CBL1 CASING BOTTOM LOGGER 1 String<br />
LOG_HDR CBL2 CASING BOTTOM LOGGER 2 String<br />
LOG_HDR CBL3 CASING BOTTOM LOGGER 3 String<br />
LOG_HDR CBL4 CASING BOTTOM LOGGER 4 String<br />
LOG_HDR CN COMPANY NAME String<br />
LOG_HDR COUN COUNTY String<br />
LOG_HDR CS1 CASING DIAMETER 1 String<br />
LOG_HDR CS2 CASING DIAMETER 2 String<br />
LOG_HDR CS3 CASING DIAMETER 3 String<br />
LOG_HDR CS4 CASING DIAMETER 4 String<br />
LOG_HDR CSW1 CASING WEIGHT 1 String<br />
LOG_HDR CSW2 CASING WEIGHT 2 String<br />
LOG_HDR CSW3 CASING WEIGHT 3 String<br />
LOG_HDR CSW4 CASING WEIGHT 4 String<br />
LOG_HDR CTRY COUNTRY String<br />
LOG_HDR DAT2 LOGGING DATE 2 String<br />
LOG_HDR DAT3 LOGGING DATE 3 String<br />
LOG_HDR DAT4 LOGGING DATE 4 String<br />
Mnemonics 9-53
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR DDEG DIRECTIONAL DEPTH String<br />
LOG_HDR DDEV DIRECTIONAL DEVIATION String<br />
LOG_HDR DFD DRILLING FLUID DENSITY String<br />
LOG_HDR DFD2 DRILLING FLUID DENSITY 2 String<br />
LOG_HDR DFD3 DRILLING FLUID DENSITY 3 String<br />
LOG_HDR DFD4 DRILLING FLUID DENSITY 4 String<br />
LOG_HDR DFL DRILLING FLUID LOSS String<br />
LOG_HDR DFL2 DRILLING FLUID LOSS 2 String<br />
LOG_HDR DFL3 DRILLING FLUID LOSS 3 String<br />
LOG_HDR DFL4 DRILLING FLUID LOSS 4 String<br />
LOG_HDR DFP2 DRILLING FLUID PH 2 String<br />
LOG_HDR DPF3 DRILLING FLUID PH 3 String<br />
LOG_HDR DFP4 DRILLING FLUID PH 4 String<br />
LOG_HDR DFPH DRILLING FLUID PH String<br />
LOG_HDR DFS SALINITY String<br />
LOG_HDR DFT DRILLING FLUID TYPE String<br />
LOG_HDR DFT2 DRILLING FLUID TYPE 2 String<br />
LOG_HDR DFT3 DRILLING FLUID TYPE 3 String<br />
LOG_HDR DFT4 DRILLING FLUID TYPE 4 String<br />
LOG_HDR DFV DRILLING FLUID VISCOSITY String<br />
LOG_HDR DFV2 DRILLING FLUID VISCOSITY 2 String<br />
LOG_HDR DFV3 DRILLING FLUID VISCOSITY 3 String<br />
LOG_HDR DFV4 DRILLING FLUID VISCOSITY 4 String<br />
LOG_HDR DKOP DIRECTIONAL KOP String<br />
LOG_HDR DMF DRILLING MEASURED FROM String<br />
LOG_HDR DRMK DIRECTIONAL REMARKS String<br />
LOG_HDR EAER EQUIP. DATA-ACOUSTIC-SERIAL NO. String<br />
LOG_HDR EAOD EQUIP. DATA-ACOUSTIC-MODEL NO. String<br />
LOG_HDR ECNT EQUIP. DATA-ACOUSTIC-NO. OF CENT String<br />
LOG_HDR EDF ELEVATION OF DRILLING FLOOR String<br />
LOG_HDR EDIA EQUIP. DATA-DENSITY-DIAMETER String<br />
LOG_HDR EDOD EQUIP. DATA-DENSITY-MODEL NO. String<br />
LOG_HDR EDSI EQUIP. DATA-GAMMA-DISTANCE TO SOURCE String<br />
LOG_HDR EDSN EQUIP. DATA-DENSITY-SOURCE SERIAL NO. String<br />
LOG_HDR EDT EQUIP. DATA-GAMMA-DETECTOR MODEL NO. String<br />
LOG_HDR EDTR EQUIP. DATA-DENSITY-STRENGTH String<br />
LOG_HDR EDUN EQUIP. DATA-DENSITY-RUN NO. String<br />
LOG_HDR EFWD EQUIP. DATA-ACOUSTIC-FWDA String<br />
LOG_HDR EGMD EQUIP. DATA-GAMMA-MODEL NO. String<br />
LOG_HDR EGRN EQUIP. DATA-GAMMA-RUN NO. String<br />
LOG_HDR EGSN EQUIP. DATA-GAMMA-SERIAL NO. String<br />
LOG_HDR EKB ELEVATION OF KELLY BUSHING String<br />
LOG_HDR ELGT EQUIP. DATA-DENSITY-LOG TYPE String<br />
LOG_HDR ELN1 EQUIP. DATA-GAMMA-LENGTH String<br />
LOG_HDR EMIA EQUIP. DATA-GAMMA-DIAMETER String<br />
LOG_HDR ENER EQUIP. DATA-DENSITY-SERIAL NO. String<br />
LOG_HDR ENG2 ENGINEER 2 NAME String<br />
LOG_HDR ENG3 ENGINEER 3 NAME String<br />
LOG_HDR RNG4 ENGINEER 4 NAME String<br />
9-54 Mnemonics
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR ENGI ENGINEER 1 NAME String<br />
LOG_HDR ENGT EQUIP. DATA-NEUTRON-LOG TYPE String<br />
LOG_HDR ENIA EQUIP. DATA-NEUTRON-DIAMETER String<br />
LOG_HDR ENOD EQUIP. DATA-NEUTRON-MODEL NO. String<br />
LOG_HDR EPD ELEVATATION OF PERMANENT DATUM String<br />
LOG_HDR EQLA EQUIP. DATA-ACOUSTIC-LSA String<br />
LOG_HDR ERUN EQUIP. DATA-ACOUSTIC-RUN NO. String<br />
LOG_HDR ESAT EQUIP. DATA-DENSITY-SOURCE TYPE String<br />
LOG_HDR ESER EQUIP. DATA-NEUTRON-SERIAL NO. String<br />
LOG_HDR ESPC EQUIP. DATA-ACOUSTIC-SPACING String<br />
LOG_HDR ESRT EQUIP. DATA-NEUTRON-SOURCE TYPE String<br />
LOG_HDR ESSN EQUIP. DATA-NEUTRON-SOURCE SERIAL NO. String<br />
LOG_HDR ESTR EQUIP. DATA-NEUTRON-STRENGTH String<br />
LOG_HDR ETP1 EQUIP. DATA-GAMMA-TYPE String<br />
LOG_HDR EURN EQUIP. DATA-NEUTRON-RUN NO. String<br />
LOG_HDR FL1 FIELD LOCATION LINE 1 String<br />
LOG_HDR FN FIELD NAME String<br />
LOG_HDR HDAT DATUM String<br />
LOG_HDR HDRT HEADER TYPE String<br />
LOG_HDR LAT LATITUDE String<br />
LOG_HDR LCC LOGGING COMPANY_CODE String<br />
LOG_HDR LCL1 LOGGING DATA-GAMMA-SCALE L 1 String<br />
LOG_HDR LCL2 LOGGING DATA-GAMMA-SCALE L 2 String<br />
LOG_HDR LCL3 LOGGING DATA-GAMMA-SCALE L 3 String<br />
LOG_HDR LCL4 LOGGING DATA-GAMMA-SCALE L 4 String<br />
LOG_HDR LCL5 LOGGING DATA-GAMMA-SCALE L 5 String<br />
LOG_HDR LCR1 LOGGING DATA-GAMMA-SCALE R 1 String<br />
LOG_HDR LCR2 LOGGING DATA-GAMMA-SCALE R 2 String<br />
LOG_HDR LCR3 LOGGING DATA-GAMMA-SCALE R 3 String<br />
LOG_HDR LCR4 LOGGING DATA-GAMMA-SCALE R 4 String<br />
LOG_HDR LCR5 LOGGING DATA-GAMMA-SCALE R 5 String<br />
LOG_HDR LDAT LDAT LOGGING DATE String<br />
LOG_HDR LDL1 LOGGING DATA-DENSITY-SCALE L 1 String<br />
LOG_HDR LDL2 LOGGING DATA-DENSITY-SCALE L 2 String<br />
LOG_HDR LDL3 LOGGING DATA-DENSITY-SCALE L 3 String<br />
LOG_HDR LDL4 LOGGING DATA-DENSITY-SCALE L 4 String<br />
LOG_HDR LDL5 LOGGING DATA-DENSITY-SCALE L 5 String<br />
LOG_HDR LDR1 LOGGING DATA-DENSITY-SCALE R 1 String<br />
LOG_HDR LDR2 LOGGING DATA-DENSITY-SCALE R 2 String<br />
LOG_HDR LDR3 LOGGING DATA-DENSITY-SCALE R 3 String<br />
LOG_HDR LDR4 LOGGING DATA-DENSITY-SCALE R 4 String<br />
LOG_HDR LDR5 LOGGING DATA-DENSITY-SCALE R 5 String<br />
LOG_HDR LDX1 LOGGING DATA-DENSITY-MATRIX 1 String<br />
LOG_HDR LDX2 LOGGING DATA-DENSITY-MATRIX 2 String<br />
LOG_HDR LDX3 LOGGING DATA-DENSITY-MATRIX 3 String<br />
LOG_HDR LDX4 LOGGING DATA-DENSITY-MATRIX 4 String<br />
LOG_HDR LDX5 LOGGING DATA-DENSITY-MATRIX 5 String<br />
LOG_HDR LFR1 LOGGING DATA-GENERAL-DEPTH FROM 1 String<br />
LOG_HDR LFR2 LOGGING DATA-GENERAL-DEPTH FROM 2 String<br />
Mnemonics 9-55
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR LFR3 LOGGING DATA-GENERAL-DEPTH FROM 3 String<br />
LOG_HDR LFR4 LOGGING DATA-GENERAL-DEPTH FROM 4 String<br />
LOG_HDR LFR5 LOGGING DATA-GENERAL-DEPTH FROM 5 String<br />
LOG_HDR LGC1 LOGGING DATA-ACOUSTIC-SCALE L 1 String<br />
LOG_HDR LGC2 LOGGING DATA-ACOUSTIC-SCALE L 2 String<br />
LOG_HDR LGC3 LOGGING DATA-ACOUSTIC-SCALE L 3 String<br />
LOG_HDR LGC4 LOGGING DATA-ACOUSTIC-SCALE L 4 String<br />
LOG_HDR LGC5 LOGGING DATA-ACOUSTIC-SCALE L 5 String<br />
LOG_HDR LMF LMF LOG MEASURED FROM String<br />
LOG_HDR LMT1 LOGGING DATA-ACOUSTIC-MATRIX 1 String<br />
LOG_HDR LMT2 LOGGING DATA-ACOUSTIC-MATRIX 2 String<br />
LOG_HDR LMT3 LOGGING DATA-ACOUSTIC-MATRIX 3 String<br />
LOG_HDR LMT4 LOGGING DATA-ACOUSTIC-MATRIX 4 String<br />
LOG_HDR LMT5 LOGGING DATA-ACOUSTIC-MATRIX 5 String<br />
LOG_HDR LMX1 LOGGING DATA-NEUTRON-MATRIX 1 String<br />
LOG_HDR LMX2 LOGGING DATA-NEUTRON-MATRIX 2 String<br />
LOG_HDR LMX3 LOGGING DATA-NEUTRON-MATRIX 3 String<br />
LOG_HDR LMX4 LOGGING DATA-NEUTRON-MATRIX 4 String<br />
LOG_HDR LMX5 LOGGING DATA-NEUTRON-MATRIX 5 String<br />
LOG_HDR LNAM LNAM String<br />
LOG_HDR LONG XLONG LONGITUDE String<br />
LOG_HDR LRU1 LOGGING DATA-GENERAL-RUN NO. 1 String<br />
LOG_HDR LRU2 LOGGING DATA-GENERAL-RUN NO. 2 String<br />
LOG_HDR LRU3 LOGGING DATA-GENERAL-RUN NO. 3 String<br />
LOG_HDR LRU4 LOGGING DATA-GENERAL-RUN NO. 4 String<br />
LOG_HDR LRU5 LOGGING DATA-GENERAL-RUN NO. 5 String<br />
LOG_HDR LSC1 LOGGING DATA-ACOUSTIC-SCALE R 1 String<br />
LOG_HDR LSC2 LOGGING DATA-ACOUSTIC-SCALE R 2 String<br />
LOG_HDR LSC3 LOGGING DATA-ACOUSTIC-SCALE R 3 String<br />
LOG_HDR LSC4 LOGGING DATA-ACOUSTIC-SCALE R 4 String<br />
LOG_HDR LSC5 LOGGING DATA-ACOUSTIC-SCALE R 5 String<br />
LOG_HDR LSL1 LOGGING DATA-NEUTRON-SCALE L 1 String<br />
LOG_HDR LSL2 LOGGING DATA-NEUTRON-SCALE L 2 String<br />
LOG_HDR LSL3 LOGGING DATA-NEUTRON-SCALE L 3 String<br />
LOG_HDR LSL4 LOGGING DATA-NEUTRON-SCALE L 4 String<br />
LOG_HDR LSL5 LOGGING DATA-NEUTRON-SCALE L 5 String<br />
LOG_HDR LSP1 LOGGING DATA-GENERAL-SPEED 1 String<br />
LOG_HDR LSP2 LOGGING DATA-GENERAL-SPEED 2 String<br />
LOG_HDR LSP3 LOGGING DATA-GENERAL-SPEED 3 String<br />
LOG_HDR LSP4 LOGGING DATA-GENERAL-SPEED 4 String<br />
LOG_HDR LSP5 LOGGING DATA-GENERAL-SPEED 5 String<br />
LOG_HDR LSR1 LOGGING DATA-NEUTRON-SCALE R 1 String<br />
LOG_HDR LSR2 LOGGING DATA-NEUTRON-SCALE R 2 String<br />
LOG_HDR LSR3 LOGGING DATA-NEUTRON-SCALE R 3 String<br />
LOG_HDR LSR4 LOGGING DATA-NEUTRON-SCALE R 4 String<br />
LOG_HDR LSR5 LOGGING DATA-NEUTRON-SCALE R 5 String<br />
LOG_HDR LSRV LSRV NAME OF SERVICE String<br />
LOG_HDR LTO1 LOGGING DATA-GENERAL-DEPTH TO 1 String<br />
LOG_HDR LTO2 LOGGING DATA-GENERAL-DEPTH TO 2 String<br />
9-56 Mnemonics
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR LTO3 LOGGING DATA-GENERAL-DEPTH TO 3 String<br />
LOG_HDR LTO4 LOGGING DATA-GENERAL-DEPTH TO 4 String<br />
LOG_HDR LTO5 LOGGING DATA-GENERAL-DEPTH TO 5 String<br />
LOG_HDR LTYP LTYP LOG TYPE String<br />
LOG_HDR LUL LUL1 LOGGING UNIT LOCATION String<br />
LOG_HDR LUL2 LUL2 LOGGING UNIT LOCATION 2 String<br />
LOG_HDR LUL3 LUL3 LOGGING UNIT LOCATION 3 String<br />
LOG_HDR LUL4 LUL4 LOGGING UNIT LOCATION 4 String<br />
LOG_HDR LUN LUN1 LOGGING UNIT NUMBER String<br />
LOG_HDR LUN2 LUN2 LOGGING UNIT NUMBER 2 String<br />
LOG_HDR LUN3 LUN3 LOGGING UNIT NUMBER 3 String<br />
LOG_HDR LUN4 LUN4 LOGGING UNIT NUMBER 4 String<br />
LOG_HDR MCS2 MCS2 MUD CAKE SAMPLE SOURCE 2 String<br />
LOG_HDR MCS3 MCS3 MUD CAKE SAMPLE SOURCE 3 String<br />
LOG_HDR MCS4 MCS4 MUD CAKE SAMPLE SOURCE 4 String<br />
LOG_HDR MCSS MCSS MUD CAKE SAMPLE SOURCE String<br />
LOG_HDR MCST TMC1 MUDCAKE SAMPLE TEMPERATURE String<br />
LOG_HDR MCT2 TMC2 MUDCAKE SAMPLE TEMPERATURE 2 String<br />
LOG_HDR MCT3 TMC3 MUDCAKE SAMPLE TEMPERATURE 3 String<br />
LOG_HDR MCT4 TMC4 MUDCAKE SAMPLE TEMPERATURE 4 String<br />
LOG_HDR MFS2 MFSS2 MUD FILTRATE SAMPLE SOURCE 2 String<br />
LOG_HDR MFS3 MFSS3 MUD FILTRATE SAMPLE SOURCE 3 String<br />
LOG_HDR MFS4 MFSS4 MUD FILTRATE SAMPLE SOURCE 4 String<br />
LOG_HDR MFSS MFSS MUD FILTRATE SAMPLE SOURCE String<br />
LOG_HDR MFST TMF1 MUD FILTRATE SAMPLE TEMPERATURE String<br />
LOG_HDR MFT2 TMF2 MUD FILTRATE SAMPLE TEMPERATURE 2 String<br />
LOG_HDR MFT3 TMF3 MUD FILTRATE SAMPLE TEMPERATURE 3 String<br />
LOG_HDR MFT4 TMF4 MUD FILTRATE SAMPLE TEMPERATURE 4 String<br />
LOG_HDR MRT MRT MAXIMUM RECORDED TEMPERATURE String<br />
LOG_HDR MRT2 MRT2 MAXIMUM RECORDED TEMPERATURE 2 String<br />
LOG_HDR MRT3 MRT3 MAXIMUM RECORDED TEMPERATURE 3 String<br />
LOG_HDR MRT4 MRT4 MAXIMUM RECORDED TEMPERATURE 4 String<br />
LOG_HDR MSS MSS SOURCE OF MUD SAMPLE String<br />
LOG_HDR MSS2 MSS2 SOURCE OF MUD SAMPLE 2 String<br />
LOG_HDR MSS3 MSS3 SOURCE OF MUD SAMPLE 3 String<br />
LOG_HDR MSS4 MSS4 SOURCE OF MUD SAMPLE 4 String<br />
LOG_HDR MST TM1 MUD SAMPLE TEMPERATURE String<br />
LOG_HDR MST2 TM2 MUD SAMPLE TEMPERATURE 2 String<br />
LOG_HDR MST3 TM3 MUD SAMPLE TEMPERATURE 3 String<br />
LOG_HDR MST4 TM4 MUD SAMPLE TEMPERATURE 4 String<br />
LOG_HDR MST TM1 MUD SAMPLE TEMPERATURE Character<br />
LOG_HDR MST2 TM2 MUD SAMPLE TEMPERATURE 2 Character<br />
LOG_HDR MST3 TM3 MUD SAMPLE TEMPERATURE 3 Character<br />
LOG_HDR MST4 TM4 MUD SAMPLE TEMPERATURE 4 Character<br />
LOG_HDR OS1 OS1 OTHER SERVICES LINE 1 String<br />
LOG_HDR OS2 OS2 OTHER SERVICES LINE 2 String<br />
LOG_HDR OS3 OS3 OTHER SERVICES LINE 3 String<br />
LOG_HDR OS4 OS4 OTHER SERVICES LINE 4 String<br />
LOG_HDR OS5 OTHER SERVICES LINE 5 String<br />
Mnemonics 9-57
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR OS6 OTHER SERVICES LINE 6 String<br />
LOG_HDR OTH1 RES. EQUIP DATA: OTHER 1 (OH) String<br />
LOG_HDR OTH2 RES. EQUIP DATA: OTHER 2 (OH) String<br />
LOG_HDR OTH3 RES. EQUIP DATA: OTHER 3 (OH) String<br />
LOG_HDR OTH4 RES. EQUIP DATA: OTHER 4 (OH) String<br />
LOG_HDR OTH5 RES. EQUIP DATA: OTHER 5 (OH) String<br />
LOG_HDR OTH6 RES. EQUIP DATA: OTHER 6 (OH) String<br />
LOG_HDR PDAT PDAT PERMANENT DATUM String<br />
LOG_HDR PGMV PROGRAM VERSION String<br />
LOG_HDR PT1 RES. EQUIP DATA: PAD TYPE 1 (OH) String<br />
LOG_HDR PT2 RES. EQUIP DATA: PAD TYPE 2 (OH) String<br />
LOG_HDR PT3 RES. EQUIP DATA: PAD TYPE 3 (OH) String<br />
LOG_HDR PT4 RES. EQUIP DATA: PAD TYPE 4 (OH) String<br />
LOG_HDR PT5 RES. EQUIP DATA: PAD TYPE 5 (OH) String<br />
LOG_HDR PT6 RES. EQUIP DATA: PAD TYPE 6 (OH) String<br />
LOG_HDR R9 REMARKS LINE 9 Character<br />
LOG_HDR R1 RMK1 REMARKS LINE 1 String<br />
LOG_HDR R10 REMARKS LINE 10 String<br />
LOG_HDR R11 REMARKS LINE 11 String<br />
LOG_HDR R12 REMARKS LINE 12 String<br />
LOG_HDR R2 RMK2 REMARKS LINE 2 String<br />
LOG_HDR R3 RMK3 REMARKS LINE 3 String<br />
LOG_HDR R4 RMK4 REMARKS LINE 4 String<br />
LOG_HDR R5 REMARKS LINE 5 String<br />
LOG_HDR R6 REMARKS LINE 6 String<br />
LOG_HDR R7 REMARKS LINE 7 String<br />
LOG_HDR R8 REMARKS LINE 8 String<br />
LOG_HDR R9 REMARKS LINE 9 String<br />
LOG_HDR RIG DRILLING RIG String<br />
LOG_HDR RMB RMBH1 RESISTIVITY OF MUD - BHT String<br />
LOG_HDR RMB2 RMBH2 RESISTIVITY OF MUD - BHT 2 String<br />
LOG_HDR RMB3 RMBH3 RESISTIVITY OF MUD - BHT 3 String<br />
LOG_HDR RMB4 RMBH4 RESISTIVITY OF MUD - BHT 4 String<br />
LOG_HDR RMC2 RMC2 RESISTIVITY OF MUD CAKE SAMPLE 2 String<br />
LOG_HDR RMC3 RMC3 RESISTIVITY OF MUD CAKE SAMPLE 3 String<br />
LOG_HDR RMC4 RMC4 RESISTIVITY OF MUD CAKE SAMPLE 4 String<br />
LOG_HDR RMCS RMCS RESISTIVITY OF MUD CAKE SAMPLE String<br />
LOG_HDR RMF2 RMF2 RESISTIVITY OF MUD FILTRATE SAMPLE 2 String<br />
LOG_HDR RMF3 RMF3 RESISTIVITY OF MUD FILTRATE SAMPLE 3 String<br />
LOG_HDR RMF4 RMF4 RESISTIVITY OF MUD FILTRATE SAMPLE 4 String<br />
LOG_HDR RMFS RMF1 RESISTIVITY OF MUD FILTRATE SAMPLE String<br />
LOG_HDR RMS RM1 RESISTIVITY OF MUD SAMPLE String<br />
LOG_HDR RMS2 RM2 RESISTIVITY OF MUD SAMPLE 2 String<br />
LOG_HDR RMS3 RM3 RESISTIVITY OF MUD SAMPLE 3 String<br />
LOG_HDR RMS4 RM4 RESISTIVITY OF MUD SAMPLE 4 String<br />
LOG_HDR RRN1 RES. EQUIP DATA: RUN NO 1 (OH) String<br />
LOG_HDR RRN2 RES. EQUIP DATA: RUN NO 2 (OH) String<br />
LOG_HDR RRN3 RES. EQUIP DATA: RUN NO 3 (OH) String<br />
LOG_HDR RRN4 RES. EQUIP DATA: RUN NO 4 (OH) String<br />
9-58 Mnemonics
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR RRN5 RES. EQUIP DATA: RUN NO 5 (OH) String<br />
LOG_HDR RRN6 RES. EQUIP DATA: RUN NO 6 (OH) String<br />
LOG_HDR RUN RUN NUMBER String<br />
LOG_HDR RUN2 RUN NUMBER 2 String<br />
LOG_HDR RUN3 RUN NUMBER 3 String<br />
LOG_HDR RUN4 RUN NUMBER 4 String<br />
LOG_HDR SDC1 RES. SCALE CHANGES: DEPTH 1 (OH) String<br />
LOG_HDR SDC2 RES. SCALE CHANGES: DEPTH 2 (OH) String<br />
LOG_HDR SDC3 RES. SCALE CHANGES: DEPTH 3 (OH) String<br />
LOG_HDR SDC4 RES. SCALE CHANGES: DEPTH 4 (OH) String<br />
LOG_HDR SDC5 RES. SCALE CHANGES: DEPTH 5 (OH) String<br />
LOG_HDR SCT1 RES. SCALE CHANGES: TYPE LOG 1 (OH) String<br />
LOG_HDR SCT2 RES. SCALE CHANGES: TYPE LOG 2 (OH) String<br />
LOG_HDR SCT3 RES. SCALE CHANGES: TYPE LOG 3 (OH) String<br />
LOG_HDR SCT4 RES. SCALE CHANGES: TYPE LOG 4 (OH) String<br />
LOG_HDR SCT5 RES. SCALE CHANGES: TYPE LOG 5 (OH) String<br />
LOG_HDR SDAT DATLOG DATE SECTION STARTED String<br />
LOG_HDR SDH1 RES. SCALE CHANGES: SCALE DOWN HOLE 1 String<br />
LOG_HDR SDH2 RES. SCALE CHANGES: SCALE DOWN HOLE 2 String<br />
LOG_HDR SDH3 RES. SCALE CHANGES: SCALE DOWN HOLE 3 String<br />
LOG_HDR SDH4 RES. SCALE CHANGES: SCALE DOWN HOLE 4 String<br />
LOG_HDR SDH5 RES. SCALE CHANGES: SCALE DOWN HOLE 5 String<br />
LOG_HDR SON SON1 SERVICE/TICKET ORDER NUMBER String<br />
LOG_HDR STAT STATE STATE String<br />
LOG_HDR STEM STEM SURFACE TEMP String<br />
LOG_HDR STIM TIMLOG TIME SECTION STARTED String<br />
LOG_HDR SUH1 RES. SCALE CHANGES: SCALE UP HOLE 1 (OH) String<br />
LOG_HDR SUH2 RES. SCALE CHANGES: SCALE UP HOLE 2 (OH) String<br />
LOG_HDR SUH3 RES. SCALE CHANGES: SCALE UP HOLE 3 (OH) String<br />
LOG_HDR SUH4 RES. SCALE CHANGES: SCALE UP HOLE 4 (OH) String<br />
LOG_HDR SUH5 RES. SCALE CHANGES: SCALE UP HOLE 5 (OH) String<br />
LOG_HDR TCS TCS TIME CIRCULATION STOPPED String<br />
LOG_HDR TCS2 TCS2 TIME CIRCULATION STOPPED 2 String<br />
LOG_HDR TCS3 TCS3 TIME CIRCULATION STOPPED 3 String<br />
LOG_HDR TCS4 TCS4 TIME CIRCULATION STOPPED 4 String<br />
LOG_HDR TDD1 TDD1 DRILLERS DEPTH 1 String<br />
LOG_HDR TDD2 TDD2 DRILLERS DEPTH 2 String<br />
LOG_HDR TDD3 TDD3 DRILLERS DEPTH 3 String<br />
LOG_HDR TDD4 TDD4 DRILLERS DEPTH 4 String<br />
LOG_HDR TDL TDL LOGGERS DEPTH String<br />
LOG_HDR TDL2 TDL2 LOGGERS DEPTH 2 String<br />
LOG_HDR TDL3 TDL3 LOGGERS DEPTH 3 String<br />
LOG_HDR TDL4 TDL4 LOGGERS DEPTH 4 String<br />
LOG_HDR TLA2 TLAB2 TIME LOGGING ON BOTTOM 2 String<br />
LOG_HDR TLA3 TLAB3 TIME LOGGING ON BOTTOM 3 String<br />
LOG_HDR TLA4 TLAB4 TIME LOGGING ON BOTTOM 4 String<br />
LOG_HDR TLAB TLAB TIME LOGGING ON BOTTOM String<br />
LOG_HDR TLI TLI TOP LOGGED INTERVAL String<br />
LOG_HDR TLI2 TLI2 TOP LOGGED INTERVAL 2 String<br />
Mnemonics 9-59
Tool<br />
LIS<br />
Mnem Mnem Description Data_Location<br />
LOG_HDR TLI3 TLI3 TOP LOGGED INTERVAL 3 String<br />
LOG_HDR TLI4 TL4 TOP LOGGED INTERVAL 4 String<br />
LOG_HDR TN1 RES. EQUIP DATA: TOOL TYPE & NO. 1 (OH) String<br />
LOG_HDR TN2 RES. EQUIP DATA: TOOL TYPE & NO. 2 (OH) String<br />
LOG_HDR TN3 RES. EQUIP DATA: TOOL TYPE & NO. 3 (OH) String<br />
LOG_HDR TN4 RES. EQUIP DATA: TOOL TYPE & NO. 4 (OH) String<br />
LOG_HDR TN5 RES. EQUIP DATA: TOOL TYPE & NO. 5 (OH) String<br />
LOG_HDR TN6 RES. EQUIP DATA: TOOL TYPE & NO. 6 (OH) String<br />
LOG_HDR TOOL TOOL TOOL STRING String<br />
LOG_HDR TPS1 RES. EQUIP DATA: TOOL POS. 1 (OH) String<br />
LOG_HDR TPS2 RES. EQUIP DATA: TOOL POS. 2 (OH) String<br />
LOG_HDR TPS3 RES. EQUIP DATA: TOOL POS. 3 (OH) String<br />
LOG_HDR TPS4 RES. EQUIP DATA: TOOL POS. 4 (OH) String<br />
LOG_HDR TPS5 RES. EQUIP DATA: TOOL POS. 5 (OH) String<br />
LOG_HDR TPS6 RES. EQUIP DATA: TOOL POS. 6 (OH) String<br />
LOG_HDR TTL1 HEADER TITLE LINE 1 String<br />
LOG_HDR TTL4 HEADER TITLE LINE 4 String<br />
LOG_HDR WIT2 WITN2 WITNESS 2 NAME String<br />
LOG_HDR WIT3 WITN3 WITNESS 3 NAME String<br />
LOG_HDR WIT4 WITN4 WITNESS 4 NAME String<br />
LOG_HDR WITN WITN1 WITNESS 1 NAME String<br />
LOG_HDR WN NAMWEL WELL NAME String<br />
LOG_HDR X X X COORDINATE String<br />
LOG_HDR XTP MAX. REC TEMP. @ 1 (OPEN HOLE) String<br />
LOG_HDR XTP2 MAX. REC TEMP. @ 2 (OPEN HOLE) String<br />
LOG_HDR XTP3 MAX. REC TEMP. @ 3 (OPEN HOLE) String<br />
LOG_HDR XTP4 MAX. REC TEMP. @ 4 (OPEN HOLE) String<br />
LOG_HDR Y Y Y COORDINATE String<br />
LOG_HDR BS BITDI BIT SIZE Character<br />
LOG_HDR CS CASDI CASING DIAMETER Character<br />
LOG_HDR CBD DEDRI CASING BOTTOM DRILLER Character<br />
LOG_HDR CBL DELOG CASING BOTTOM LOGGER Character<br />
LOG_HDR CSW CASWE CASING WEIGHT Character<br />
LOG_HDR TDD TDD DRILLERS DEPTH Character<br />
9-60 Mnemonics
Index<br />
A<br />
Acoustics 3-24<br />
BSAT Borehole Compensated Sonic<br />
Array Tool 3-24<br />
FWS Full Wave Sonic Tool 3-27<br />
WaveSonic® Tool 3-25<br />
Acoustics <strong>and</strong> Rock Properties 2-30<br />
AcidXpert Analysis 2-36<br />
Anisotropy Analysis 2-30<br />
FracXpert Analysis 2-34<br />
RockXpert2 Analysis 2-32<br />
Advanced Measurement System<br />
Electronic Advanced Measurement System<br />
(Portable) 7-26<br />
JobTrak® Data Job Logger 7-28<br />
SmartETD® System 7-27<br />
Advanced Measurement System (AMS) 7-25<br />
Advanced® Slickline <strong>Services</strong> 7-16<br />
Deepwater Riserless Subsea Light Well<br />
Intervention System 7-33<br />
DPU® Downhole Power Unit 7-19<br />
DPU Tubing Punch 7-22<br />
LineTrak® Slickline Inspection Device <strong>and</strong> Wire<br />
Management Program 7-31<br />
Memory Production Logging (MPL) Service 7-29<br />
Ancillary Equipment 5-71<br />
Annular Pressure-Control Line Swivel Sub 5-92<br />
Annular Pressure-Control Line Tubing Release 5-93<br />
Annular Pressure-Control Line Vent 5-91<br />
AutoLatch Release Gun Connector 5-75<br />
Automatic Release 5-99<br />
Automatic-Release Gun Hanger—<br />
Automatic-J M<strong>and</strong>rel 5-84<br />
Automatic-Release Gun Hanger—<br />
Rotational Set 5-82<br />
Balanced Isolation Tool 5-72<br />
Bar Pressure Vent 5-94<br />
Below-Packer Vent Device 5-95<br />
Centralizer T<strong>and</strong>em 5-89<br />
Detach Separating Gun Connector 5-79<br />
DPU Downhole Power Unit 5-104<br />
Emergency Release Assembly 5-90<br />
Explosive Transfer Swivel Sub 5-86<br />
EZ Pass Gun Hanger 5-80<br />
Fast Gauge Recorder 5-110<br />
Fill Disk Assembly 5-71<br />
Gamma Perforator Logging Tool 5-112<br />
Gun Guides 5-107<br />
Hydraulic Metering Release Tool for the Single<br />
Trip System (STPP-GH) Tool 5-108<br />
Isolation Sub-Assembly 5-76<br />
Maximum Differential Bar Vent 5-96<br />
Mechanical Tubing Release 5-101<br />
Pressure-Actuated Tubing Release 5-103<br />
Pressure-Operated Vent 5-97<br />
Quick Torque Connector 5-77<br />
Ratchet Gun Connector 5-74<br />
Roller T<strong>and</strong>em Assembly 5-88<br />
Shearable Safety Sub 5-87<br />
SmartETD® Advanced Electronic Triggering<br />
Device 5-105<br />
Vann Circulating Valve 5-98<br />
Y-Block Assembly 5-106<br />
Auxiliary <strong>Services</strong> 3-57<br />
BHPT Borehole Properties Tool 3-63<br />
CTL Coiled Tubing Logging 3-62<br />
FIAC Four Independent Arm Caliper Tool 3-65<br />
Multi-Conductor LockJar®* System 3-57<br />
RWCH Releaseable <strong>Wireline</strong> Cable Head 3-59<br />
SDDT St<strong>and</strong>-Alone DITS Directional Tool 3-67<br />
Toolpusher Logging (TPL) Service 3-60<br />
Index 10-1<br />
B<br />
Borehole Geophysics 2-26, 3-33<br />
Reservoir Geophysics 2-27, 3-34<br />
GeoChain VSP Downhole Receiver<br />
Array 2-27, 3-34<br />
Long Array Multi-Component Acquisition<br />
Tools 2-27, 3-34<br />
Synthetic Seismic <strong>and</strong> Sonic Log<br />
Calibration 2-27, 3-34<br />
ExactFrac® <strong>Services</strong> 2-29, 3-36<br />
Vertical Incidence Vertical Seismic<br />
Profiling (VIVSP) Analysis 2-28, 3-35<br />
Wellbore Seismic 2-26, 3-33<br />
High Resolution Seismic Imaging 2-26, 3-33<br />
C<br />
Cased-Hole <strong>Wireline</strong> <strong>and</strong> <strong>Perforating</strong> <strong>Services</strong> 4-1<br />
Casing <strong>and</strong> Tubing Evaluation 4-28<br />
CAST-V Circumferential Acoustic Scanning<br />
Tool-Visualization 4-29<br />
MAC Multi-Arm Caliper Tool 4-28<br />
*LockJar is a registered trademark of Evans Engineering, Inc.
The FASTCAST Fast Circumferential Acoustic<br />
Scanning Tool 4-31<br />
Cement Evaluation 4-33<br />
ACE Advanced Cement Evaluation Process 4-37<br />
Cement Bond Log (CBL) 4-33<br />
Radial Cement Bond Tools 4-35<br />
CollarTrak® Slickline Collar Locator 7-23<br />
D<br />
Detonators 5-113<br />
Block RED® Detonators 5-115<br />
Capsule RED Detonators 5-113<br />
RED GO-Style Thermal Igniter 5-114<br />
Top Fire RED Detonators 5-116<br />
Downhole Video 6-1<br />
Downhole Video <strong>Services</strong> 6-1<br />
EyeDeal Camera System 6-4<br />
Fiber-Optic Camera System 6-3<br />
Hawkeye Camera System 6-2<br />
Dynamic Modeling 5-117<br />
Near-Wellbore Stimulation <strong>and</strong><br />
PulsFrac Software 5-120<br />
PerfPro® Process 5-117<br />
Predicting In-Situ Charge Performance 5-117<br />
ShockPro SM Shockload Evaluation Service 5-125<br />
SurgePro SM Service 5-122<br />
F<br />
Firing Heads 5-45<br />
Annulus Pressure Crossover Assembly 5-67<br />
Annulus Pressure Firer-Control Line 5-54<br />
Annulus Pressure Transfer Reservoir 5-55<br />
Detonation Interruption Device 5-45<br />
Differential Firing Head 5-57<br />
Extended Delay Fuses 5-63<br />
EZ Cycle Multi-Pressure Cycle Firing Head 5-68<br />
Hydraulic-Actuator Firing Head <strong>and</strong> Swivel-Type<br />
Hydraulic-Actuator Firing Head 5-58<br />
Mechanical Firing Head 5-46<br />
Mechanical Metering Hydraulic-Delay<br />
Firing Head 5-59<br />
Model II-D Mechanical Firing Head 5-47<br />
Model III-D Mechanical Firing Head 5-48<br />
Model K <strong>and</strong> K-II Firing Heads 5-50<br />
Model KV-II Firing Head 5-51<br />
Modular Mechanical Firing Head 5-64<br />
Drop Bar Options 5-65<br />
Skirt-Centralizer Selection Chart 5-65<br />
Multiaction-Delay Firing Head 5-53<br />
Pressure-Actuated Firing Head 5-49<br />
Pump-Through Firing Head 5-70<br />
Side-Pocket M<strong>and</strong>rel Firing Head 5-66<br />
Slickline-Retrievable Mechanical Firing Head 5-60<br />
Slickline-Retrievable Time-Delay Firer<br />
Firing Head 5-62<br />
Slimhole Annulus Pressure Firer—<br />
Internal Control 5-56<br />
Time-Delay Firer 5-52<br />
Formation Evaluation 4-1<br />
CASE Casing Evaluation <strong>and</strong> Inspection<br />
Software 4-10<br />
DSN Dual-Spaced Neutron Tool 4-7<br />
FCMT Formation Compaction Monitoring Tool 4-9<br />
RMT Elite Reservoir Monitor Tool 4-3<br />
Spectra Flow Logging Service (SpFl) 4-5<br />
TMD-L Thermal Multigate Decay-Lithology<br />
Logging Tool 4-1<br />
10-2 Index<br />
G<br />
Gun Systems 5-10<br />
Capsule Gun Systems 5-41<br />
Deep Star Capsule Gun 5-42<br />
Dyna-Star® Capsule Gun 5-41<br />
Ported Gun <strong>Perforating</strong> System 5-44<br />
VannGun® Assemblies<br />
1 9/16 in. to 7 in. <strong>and</strong> 4 SPF to 21 SPF 5-10<br />
Gun Swell Information 5-39<br />
Gun Washover/Fishing Specifications 5-38<br />
Tensile Ratings 5-16<br />
1 9/16-in. Premium VannGun<br />
Assemblies 5-16<br />
2-in. Premium VannGun<br />
Assemblies 5-17<br />
2 1/2-in. Premium VannGun<br />
Assemblies 5-18<br />
2 3/4-in. Premium VannGun<br />
Assemblies 5-19<br />
2 7/8-in. Premium VannGun<br />
Assemblies 5-20<br />
3 3/8-in. Premium VannGun<br />
Assemblies 5-21<br />
4-in. Premium VannGun<br />
Assemblies 5-23<br />
4 1/2-in. Premium VannGun<br />
Assemblies 5-24<br />
4 5/8-in. Premium VannGun<br />
Assemblies 5-25<br />
4 3/4-in. Premium VannGun<br />
Assemblies 5-28
H<br />
5-in. Premium VannGun®<br />
Assemblies 5-29<br />
5 1/8-in. Premium VannGun<br />
Assemblies 5-31<br />
5 3/4-in. Premium VannGun<br />
Assemblies 5-33<br />
6-in. Premium VannGun<br />
Assemblies 5-33<br />
6 1/2-in. High-Pressure Premium<br />
VannGun Assemblies 5-35<br />
6 1/2-in. Premium VannGun<br />
Assemblies 5-34<br />
7-in. Premium VannGun<br />
Assemblies 5-36<br />
VannGun Phasing <strong>and</strong> Shot Patterns 5-11<br />
0° Phasing 4 <strong>and</strong> 5 SPF 5-11<br />
138° Phasing 14 SPF 5-15<br />
140°/160° Phasing 11 SPF 5-14<br />
180° Phasing 4 <strong>and</strong> 8 SPF 5-12<br />
25.7°/128.5° Phasing 14 SPF 5-15<br />
30°/150° Phasing 12 SPF 5-14<br />
45°/135° Phasing 5, 6, 8, 12, <strong>and</strong> 18 SPF 5-13<br />
51.4°/154.3° Phasing 12 SPF 5-14<br />
60° Phasing 4, 5, <strong>and</strong> 6 SPF 5-11<br />
60° Phasing 6 SPF Two Planes 5-13<br />
60°/120° Phasing 18 <strong>and</strong> 21 SPF 5-15<br />
90° Phasing 4 SPF 5-12<br />
HalLink® Satellite Systems 1-2<br />
Hostile—Slimhole Formation Evaluation 3-47<br />
HEAT Hostile Environment Applications<br />
Tool Suite 3-47<br />
HDSN Hostile Dual-Spaced Neutron<br />
Tool 3-53<br />
HEDL Hostile Environment Dual Laterolog<br />
Tool 3-48<br />
HFWS Hostile Full Wave Sonic Tool 3-49<br />
HNGR Hostile Natural Gamma Ray<br />
Tool 3-55<br />
HSDL Hostile Spectral Density Log 3-51<br />
HSFT Hostile Sequential Formation Tester<br />
Tool 3-56<br />
I<br />
Imaging 3-9<br />
CAST-V Circumferential Acoustic Scanning<br />
Tool-Visualization 3-15<br />
EMI Electrical Micro Imaging Service 3-9<br />
OMRI Oil-Based Micro-Imager Tool 3-13<br />
SED Six Arm Dipmeter 3-16<br />
XRMI X-Tended Range Micro Imager Tool 3-11<br />
InSite Anywhere® Service 1-3<br />
Index 10-3<br />
K<br />
Knowledge <strong>and</strong> Data Transfer 1-1<br />
L<br />
LOGIQ Logging Truck 8-1<br />
LOGIQ Modular Skid Unit 8-3<br />
M<br />
Mechanical <strong>Services</strong> 4-39<br />
C-4 Casing Cutters 4-50<br />
Casing <strong>and</strong> Drillpipe Cutters 4-48<br />
Chemical Cutter 4-39<br />
Coiled Tubing Cutters 4-46<br />
Drill Collar Severing Tool 4-51<br />
Junk Shot 4-53<br />
Pipe Recovery 4-39<br />
Super Tubing Cutters 4-44<br />
Tubing Cutters 4-42<br />
Mnemonics 9-1<br />
Log Header Mnemonics 9-44<br />
Mobilization 8-1<br />
N<br />
Near-Wellbore Stimulation 5-127<br />
PerfStim Process 5-133<br />
POWR*PERF SM Perforation/Stimulation<br />
Process 5-132<br />
Propellent Stimulation Tool Assembly 5-130<br />
StimGun* Assembly 5-127<br />
NMR 3-29<br />
MRILab® Magnetic Resonance Image Fluid<br />
Analyzer 3-31<br />
MRIL-XL <strong>and</strong> MRIL®-Prime Magnetic Resonance<br />
Image Logging Tools 3-29<br />
Nuclear 3-17<br />
CSNG Compensated Spectral Natural Gamma<br />
Ray 3-22<br />
DSEN Dual-Spaced Epithermal Neutron Log<br />
Tool 3-21<br />
DSN Dual-Spaced Neutron Tool 3-19<br />
SDL Spectral Density Log 3-17<br />
*StimGun is a trademark of Marathon Oil Company.
O<br />
Open-Hole <strong>Wireline</strong> <strong>and</strong> <strong>Perforating</strong> <strong>Services</strong> 3-1<br />
Oriented <strong>Perforating</strong> 5-134<br />
Eccentric Orienting T<strong>and</strong>em 5-138<br />
Finned Orienting T<strong>and</strong>em 5-137<br />
G-Force® Precision Oriented <strong>Perforating</strong><br />
System 5-134<br />
Oriented <strong>Perforating</strong> with Modular Guns 5-136<br />
P<br />
<strong>Perforating</strong> Solutions 5-1<br />
Petrophysics 2-1<br />
MRI Petrophysics 2-1<br />
Diffusion Analysis (DIFAN) 2-5<br />
Enhanced Diffusion Method (EDM)<br />
Technique 2-6<br />
Heavy Oil MRIAN SM Service 2-7<br />
MRIAN Magnetic Resonance Imaging<br />
Analysis 2-2<br />
MRIL® Simultaneous T1 <strong>and</strong> T2<br />
Measurements 2-1<br />
StiMRIL Process 2-8<br />
Time Domain Analysis (TDA) 2-4<br />
Volumetric Petrophysics 2-10<br />
Chi Modeling® Computation Service 2-10<br />
CORAL Complex Lithology Analysis 2-15<br />
LARA Laminated Reservoir Analysis 2-16<br />
SASHA Shaly S<strong>and</strong> Analysis 2-14<br />
ULTRA Module Suite 2-12<br />
Plug Setting Equipment 4-54<br />
EZ Drill® Bridge Plugs 4-54<br />
Fas Drill® Bridge Plugs 4-55<br />
Production Logging 4-18<br />
FloImager® Service 4-21<br />
GHT Gas Holdup Tool 4-23<br />
MPL Memory Production Logging Tool 4-24<br />
Production Logging Tools 4-18<br />
Quartz Pressure Tool 4-27<br />
R<br />
Real-Time Operations 1-1<br />
Real-Time Data/Solution Delivery 1-1<br />
Reservoir <strong>and</strong> Production Engineering 2-38<br />
FloImager Analysis Service 2-54<br />
FloImager® 3D Software Analysis 2-54<br />
Production Logging Analysis 2-51<br />
Reservoir Evaluation 2-48<br />
CarbOxSat Model 2-49<br />
SigmaSat Model 2-48<br />
TripleSat Model 2-50<br />
Reservoir Testing Studio 2-38<br />
Exact Anisotropy Analysis Plot 2-39<br />
Exact Buildup Analysis 2-39<br />
FasTest® Buildup Analysis 2-40<br />
Formation Test Summary Program (FTS) 2-42<br />
Horner Time Plots 2-40<br />
Log-Log Derivative Analysis Plot 2-41<br />
PVT Analysis 2-42<br />
Well Testing 2-44<br />
Reservoir Characterization 2-17<br />
Borehole Image Analysis 2-17<br />
AutoDip <strong>and</strong> TrendSetter <strong>Services</strong> 2-17<br />
Facies Profile 2-22<br />
ReadyView Open-Hole Imaging 2-20<br />
ImagePerm 2-25<br />
Net2Gross S<strong>and</strong> Count 2-24<br />
Reservoir Evaluation <strong>Services</strong> 2-1<br />
Resistivity 3-1<br />
ACRt Array Compensated Resistivity Tool<br />
System 3-1<br />
DLL Dual Laterolog Service 3-6<br />
HDIL Hostile Dual Induction Log 3-5<br />
HFDT High Frequency Dielectric Tool 3-8<br />
HRAI High Resolution Array Induction Tool 3-3<br />
HRI High Resolution Induction Tool 3-4<br />
MSFL Micro-Spherically Focused Log <strong>and</strong><br />
Microlog (ML) 3-7<br />
10-4 Index<br />
S<br />
Sampling 3-37<br />
HRSCT Hostile Rotary Side Wall Coring Tool 3-46<br />
Hydraulic Valve Section 3-46<br />
M<strong>and</strong>rel Section 3-46<br />
Motor Drive Section 3-46<br />
RDT Reservoir Description Tool 3-37<br />
CVS Chamber Valve Section 3-40<br />
DPS Dual Probe Section 3-39<br />
FPS Flow-Control Pump-Out Section 3-39<br />
MCS Multi Chamber Section 3-40<br />
MRILab® Section 3-40<br />
Oval Pad 3-39<br />
QGS Quartz Gauge Section 3-39<br />
Straddle Packer 3-39<br />
RSCT Rotary Sidewall Coring Tool 3-43<br />
SFT-IV Sequential Formation Tester IV Tool 3-41<br />
SFTT Sequential Formation Test Tool 3-42<br />
SWC Side Wall Coring Tool 3-45<br />
Shaped Charges 5-1<br />
Charge Performance Data 5-7<br />
Dominator® Shaped Charges 5-2
KISS Low-Damage <strong>Perforating</strong> Charge 5-6<br />
MaxForce Shaped Charges 5-1<br />
Maxim Shaped Charges 5-5<br />
Mirage® Shaped Charges 5-3<br />
Slickline Service Equipment <strong>and</strong> <strong>Services</strong> 7-1<br />
Slickline Skid Units <strong>and</strong> Trucks 7-14<br />
Special Applications 5-139<br />
Coiled Tubing Conveyed <strong>Perforating</strong> 5-142<br />
DrillGun <strong>Perforating</strong> Systems 5-143<br />
Modular Gun System 5-139<br />
Select Fire Systems 5-141<br />
Setting Tools for the Auto-Release Gun Hanger 5-145<br />
Subsurface Service Tools 7-2<br />
Auxiliary Tools For Use with Slickline Toolstring 7-6<br />
Exp<strong>and</strong>able Wirefinder 7-7<br />
Otis® Go-Devil 7-7<br />
Otis M Magnetic Fishing Tool 7-6<br />
Otis P <strong>Wireline</strong> Grab 7-7<br />
Otis Tubing Broach 7-6<br />
Otis G Fishing Socket 7-7<br />
Otis Gauge Cutter <strong>and</strong> Swaging Tools 7-6<br />
Otis Impression Tool 7-6<br />
Otis Quick Connect Toolstring Connection 7-5<br />
Plugs For Wells Without L<strong>and</strong>ing Nipples 7-10<br />
Monolock® Plug 7-10<br />
Positioning Tools 7-12<br />
Otis BO Selective Positioning Tools 7-12<br />
Pulling Tools 7-9<br />
External Fishing Necks 7-9<br />
Internal Fishing Necks 7-9<br />
Running Tools 7-8<br />
Otis MR Running Tools 7-8<br />
Otis RXN Running Tools 7-8<br />
Otis SAFETYSET® Running Tools 7-8<br />
Otis UP Running Tool 7-8<br />
Otis X® <strong>and</strong> R® Running Tools 7-8<br />
Slickline Detent Jars 7-4<br />
Slickline Service Tools 7-2<br />
Slickline Toolstring 7-2<br />
Otis Accelerators 7-3<br />
Otis B Blind Box 7-3<br />
Otis Jars 7-3<br />
Otis Knuckle Joints 7-3<br />
Otis Rope Sockets 7-2<br />
Otis Stems 7-2<br />
<strong>Wireline</strong> Toolstring 7-2<br />
Test Tools 7-11<br />
Otis Non-Selective Test Tools 7-11<br />
Tubing Perforators <strong>and</strong> Bailers 7-13<br />
Surface Service Equipment 7-15<br />
Index 10-5<br />
T<br />
Through Casing Acoustic <strong>Services</strong> 4-12<br />
FWS Full Wave Sonic Tool 4-14<br />
HFWS Hostile Full Wave Sonic Tool 4-16<br />
WaveSonic Tool 4-12
10-6 Index