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Baker Hughes Drilling Services Overview
© 2015 Baker Hughes Incorporated. All Rights Reserved.
Bob Sharpe – Business Development Manager – Drilling Services UK Iain Sivers – Business Development Manager – Drilling Services UK
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© 2015 BAKE R HUGH E S INCOR P O R A T E D. ALL RIGHT S RESE R V E D . T ERMS AND CON DIT I O N S OF USE: BY ACCE PT I N G T HIS DOCUM E NT , T HE RECIPI E N T AGRE E S T HAT T HE DOC UM E NT T O G ET H E R WIT H AL L I NF O RM AT I O N I NCLUD E D T HEREI N I S T HE CONF I D E NT I AL AND PROP R I ET A R Y PROP E RT Y OF BAKE R HUG H E S INCO R P O R AT E D AND INCLU D E S VALUA BL E T RADE SECR ET S AND/O R PRO P RI ET A R Y INF ORMAT I O N OF BAKE R HUGH E S ( COLLE CT I V EL Y "INF O RM AT I O N " ) . BAKE R HUG H E S RET AIN S ALL RIGHT S UND E R COPY R I G HT LAWS AND T RADE SECR ET LAWS OF T HE UNIT E D ST AT ES OF AMERIC A AND OT HER COU NT RI E S . T HE RECIPI E NT F URT HER AGRE E S T HAT T HE DOC UM E NT M AY NOT BE DIST RI B UT E D, T RANSM IT T E D , COPIE D OR REPR O D U C E D IN WHOLE OR IN PART BY ANY MEANS, ELECT R O NI C , MECHA NI C AL, OR OT HER WI S E, WIT HOUT T HE EXPR E S S PRIO R WRIT T EN CONS E NT OF BAKE R HUG H E S, AND M AY NOT BE USED DIRE CT L Y OR INDIRE CT L Y IN ANY WAY DET RIM E NT AL T O BAKE R HUGH E S ’ INT ERE ST .
© 2015 Baker Hughes Incorporated. All Rights Reserved.
Agenda • • •
Directional Drilling Motors Rotary Steerable Steerable Drilling Liner
• • •
Formation Evaluation MWD Platforms & Mud Pulse Telemetry Directional / Gamma Ray / Resistivity High Level Formation Evaluation Services
Drill Bit Technology • PDC & Tri-cone technology
2
HSE – Baker Hughes HSE Culture
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The "Life Rules!" program targets 10 life-critical safety hazards within Baker Hughes.
33
Baker Hughes Directional Drilling Solutions Conventional Drilling Systems Steerable Motors
Ultra™ Motors
© 2015 Baker Hughes Incorporated. All Rights Reserved.
Ultra X-treme™ Motors
X-treme™ Motors
Automated Drilling Systems 3D Rotary Steerable Systems
Vertical and Low Inclination Solutions
AutoTrak™ eXact
AutoTrak™ V
SureTrak™
AutoTrak™ Curve
TruTrak™
CoilTrak™
AutoTrak™ eXpress AutoTrak™ G3 AutoTrak™ X-treme
4
Special Drilling Solutions
Through-Tubing Rotary Drilling
Drilling Technology Development Navi-Drill
Steerable Motor Technology
Ultra Series X-treme Ultra X-treme New Gen Motor (7"Ultra XL45, 6¾"Ultra Curve & 5"X-treme eXtend
Automated Slide Drilling Systems
VertiTrak TruTrak TruTrak 4 ¾” (Jointed Pipe & Coil) AutoTrak 1.5 AutoTrak 2.5 AutoTrak G3.0
Rotary Steerable Systems
AutoTrak X-treme
© 2015 Baker Hughes Incorporated. All Rights Reserved.
AutoTrak 4-3/4” AutoTrak eXpress AutoTrak V AutoTrak Curve AutoTrak eXact Orient Express CoilTrak
Coiled Tubing BHA
Rib Steered Motor 5
1970
1980
1990
2000
2010
2015
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Motors
6
Motor offering Ultra
X-treme
Ultra-Xtreme
■ ■ ■ ■ ■ ■ ■ ■ ■ ■
HS TS AD X XL RF RS LS VS IR
High Speed Turbine Speed Air Drilling/Mud Short Ultra Motor Extended Length Reduced Flow Reduced Speed Low Speed Very Low Speed Intermediate Radius
© 2015 Baker Hughes Incorporated. All Rights Reserved.
■ UTR ■ UXT ■ XTR
7
Ultra Series Ultra X-treme Series X-treme series
Motor power output development X-treme ®
1200
1000
4-3/4" 6-3/4"
Power Output (HP)
9-1/2"
800
600
ULTRA
400
Navi-Drill
© 2015 Baker Hughes Incorporated. All Rights Reserved.
200
0 1985
8
1990
1995
2000
2005
2009
Power Section Technology
Steel Elastomer
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Standard Power Section : X-treme Technology Power Section : steel tube with cylindrical ID pre-contoured Steel tube less leakage between the chambers diff. rubber layer thickness
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Improved volumetric efficiency thin & “equidistant” rubber layer less shrinking or swelling less heat is built up heat can be dissipated easier
DuraMax High Performance Elastomer
© 2015 Baker Hughes Incorporated. All Rights Reserved.
■ Ultra–HP motors ■ Cost effective high performance solution ■ Primary usage in US and Canada, >25,000 circ hrs ■ Sizes 4-¾”, 6-½”, 6 ¾” and 8” ■ Delivers: – 50% higher torque than standard Ultra Series – Durability in difficult drilling environments – High reliability ■ Results: – extended runs – significant increases in section ROPs
10
NEW
Further advances in Motor Technology – Significant developments in Vertical, Build and 6 inch motor capability.
© 2015 Baker Hughes Incorporated. All Rights Reserved.
Vertical Sections
Hi DLS Capability - 21.5˚/100 ft 11
Comparisons
1,025 hp © 2015 Baker Hughes Incorporated. All Rights Reserved.
750 hp 700 hp 560 hp BWM M5 F10
12
Formula One Lamborghini Aventador LP-700
9-1/2” X-treme High Speed Motor
AutoTrak G3/ X-treme - Advanced RSS Services ■ Advanced Automated Rotary Closed-Loop Steering ■ Integrated Formation Evaluation Systems ■ Reservoir Navigation Service ■ High Resolution Imaging Services Reservoir Eng. Geophysical Geological Petrophysical
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Drilling/ Steering
OnTrak™ MWD/LWD including Telemetry
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AutoTrak Steering Unit
AutoTrak G3/ X-treme - Advanced RSS Services ■ Advanced Automated Rotary Closed-Loop Steering ■ Integrated Formation Evaluation Systems ■ Reservoir Navigation Service ■ High Resolution Imaging Services Reservoir Eng.
AdvancedGeophysical Inclination Hold Mode Geological Petrophysical
Adaptive Center Force Mode
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Drilling/ Steering
OnTrak™ MWD/LWD including Telemetry
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AutoTrak Steering Unit
AutoTrak – Steering System Features Rotating drive shaft
Mud Lubricated Bearings
Wireless Power and Communication Link
Micro hydraulic modules
Steering ribs
Control electronics and inclination sensors
© 2015 Baker Hughes Incorporated. All Rights Reserved.
Non rotating steerable stabilizer sleeve
15 15
AutoTrak – Steering Principle Direction High Side
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Steering Vector
Click for animation
16 16
Reliable Steering in Dynamic Environments ■ No loss of control in stick-slip situations the steering action from string rotation. No risk of hanging, sticking or damage Ribs can fully retract into the sleeve so
© 2015 Baker Hughes Incorporated. All Rights Reserved.
it can freely rotate in the borehole
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Clearance for free rotation
The AutoTrak steering sleeve decouples
Easy Control with Automatic Downlinking System ■ “Negative” mud pulse telemetry from surface to downhole ■ Bypass actuator diverts 15% of mud flow in pulses ■ Computer controlled automated operation ■ Versatile commands while drilling ahead
Bypass Outlet – To Mud Pits
– MWD & LWD parameters © 2015 Baker Hughes Incorporated. All Rights Reserved.
– Steering Modes – Directional Targets ■ Remote control from collaboration center possible Inlet ‐ To Standpipe 18
AutoTrak Capability...? VERTICAL
DIRECTIONAL ■ Baker Hughes Solution and Results
© 2015 Baker Hughes Incorporated. All Rights Reserved.
– Turn the wellpath 255° with a continuous 5°/100ft DLS to enter the reservoir – Precisely steer a complex profile in a known difficult drilling environment (harsh vibration conditions in chalk, unconsolidated reservoir sands)
Baker Hughes Solution and Results Excellent verticality achieved with the AutoTrak run with inclinations less than 0.04°. 7912 feet MD drilled in one run at 48 ft/hr ROP 19
© 2015 Baker Hughes Incorporated. All Rights Reserved.
AutoTrak X-treme - Integrated Motor Power
20
AutoTrak™ Curve Rotary Steerable System
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■Smooth, Fast Runs to Reduce Time on Wells in Unconventional Plays
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The Difference: Design
Directional control Fewer components Improved reliability Rugged for harsh terrains • Optional battery • Integrated Baker Hughes Bit Technology • One-piece design
© 2015 Baker Hughes Incorporated. All Rights Reserved.
• • • •
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The BHA deliverable meeting the market needs 39.4 ft 3.3 ft 13.1 ft
Nonmag Spacing: 18 ft
Dir. Ele
3.3 ft
18 ft Dir. Sensor
Azi-Gamma
4.9 ft
NB Inc.
Gamma Sensor Spacing: 11 ft
Flex Assembly Power and Pulser
© 2015 Baker Hughes Incorporated. All Rights Reserved.
• •
• Length extended for more flexibility • Directional & Azi-Gamma sensor located
in flex to be near-to-bit Designed for LCM applications Additional power overhead for resistivity in the future
High BUR PDC Bit
• HCC technology
optimized design on bit characteristics for High BUR RSS
Modified Steering Unit
• Higher steering forces delivered • Shorter drive sub & additional rib • •
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extension Updated sensor package for oriented kick from vertical Diamond bearings Greatly simplified & updated electronics
The Difference: The AutoTrak Legacy • Drills build rate of 15°/100’ • Tolerates higher LCM content • Offers near bit gamma ray • Optional flow-off survey • Runs with a standard motor • Integrates Baker Hughes bit
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Pulser/ Power
Steering Unit
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Directional MWD
Near Bit Gamma
Near Bit Inclination
The Proof: Actual Time and Cost Savings In January 2012 $9.75mm saved In December 2012
© 2015 Baker Hughes Incorporated. All Rights Reserved.
SLB Archer (450,000 ft as of October 2012) BH AutoTrak Curve 2.2 million ft - October 2012 and 3 million ft - December 2012 In April 2013 678 Wells Drilled, 4,000,000 ft Q1 2015 – Over 15,000,000 feet Drilled… 25
© 2015 Baker Hughes Incorporated. All Rights Reserved.
AutoTrak™ eXact Rotary Steerable System
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AutoTrak™ eXact Rotary Steerable System • Continued development from AutoTrak and AutoTrak Curve
▪ New Modular RSS incl. Advanced LWD ▪ Higher BUR capability up to 12°/100’ ▪ New Steering Unit design
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– New Steering pad setup – Rugged with fewer components (no rotary seals in the steering unit). – Higher WOB capability. ▪ Baker Hughes system approach – Available in 6 ¾” and 4 ¾” tools
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AutoTrak™ eXact Rotary Steerable System • Continued development from AutoTrak and AutoTrak Curve Increased efficiency • Oriented kick-off from vertical • Higher BUR capability • High frequency VSS measurement near bit.
© 2015 Baker Hughes Incorporated. All Rights Reserved.
Precise wellbore placement • Advanced formation evaluation LWD package • Early detection of bed boundaries • Constant steering performance independent of bit hydraulics.
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Reduced risk • Avoid directional work in troublesome formations and casing run efficiency • Superior borehole quality
AutoTrak™ eXact Rotary Steerable System • Continued development from AutoTrak and AutoTrak Curve
Developed in the Celle Technology Centre, Germany • Currently being used in KSA, UAE, USA, China & Oman Planned application • 6 ¾”tools will replace the AutoTrak ™ G3 steering unit fleet.
© 2015 Baker Hughes Incorporated. All Rights Reserved.
4 ¾”Tools • Currently being deployed in KSA as a solution to the harsh drilling conditions.
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Automated Drilling Systems - Features TruTrak
AutoTrak eXpress
AutoTrak G3
AutoTrak AutoTrak X‐treme Curve
AutoTrak eXact
Automatic, Continuous Steering Continuous Drillstring Rotation
*
Mud Motor Powered
*
*
*
Near Bit Inclination Directional MWD © 2015 Baker Hughes Incorporated. All Rights Reserved.
Modular LWD‐FE Downlink While Drilling High Speed Telemetry * Requires special “Modular” Motor 30
Standard
Optional
Not Available
© 2015 Baker Hughes Incorporated. All Rights Reserved.
SureTrakTM
■Steerable Drilling Liner Service
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System Overview ■ Flexible system that can circulate, rotate, drill, log and set liner in one run ■ Sizes: – 9 5/8” SureTrakTM : 8 ½” x 12 ¼” – 7” SureTrakTM : 6” x 8 ½”
■ Benefits & Features:
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– Flexible Stick-out BHA length – Provides required LWD/MWD – Drill 3D wells & horizontal sections – Doesn’t require any rig modification – Retrievable BHA ■ Turn the irrecoverable reserves into recoverable
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System Overview ■ Outer String: – Liner – Setting Tool – Reamer Bit
© 2015 Baker Hughes Incorporated. All Rights Reserved.
■ Inner String: – Drill Pipe – Inner BHA
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■ Motor driven components – Reamer Bit – Pilot BHA ■ Stick out / Pilot BHA – Directional – FE tools
System Overview
Thruster
Setting Tool
BCPM
Smart Battery Sub
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System Components • Standard • Modified • New Developments 34
Liner
Modular Motor
Reamer Bit
Reamer Drive Sub
Pilot BHA
System Overview
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Rotation • Liner can be rotated from surface • Pilot BHA rotates with motor RPM (+ string RPM) • Reamer Bit rotates with motor RPM if connected (+ string RPM) 35
System Overview
Modular Motor
Pilot Bit
Setting Tool © 2015 Baker Hughes Incorporated. All Rights Reserved.
Flow Path • Setting Tool provides metal seal between inner and outer string • Approx. 95% of flow rate exits at Pilot Bit • Approx. 5% exit at Modular Motor Lower Bearing. This hinders cuttings from entering liner string 36
Case History 7” SureTrakTM application Offshore North Sea
© 2015 Baker Hughes Incorporated. All Rights Reserved.
Location: Offshore North Sea Operator: Statoil Date: September 2012 Hole Size: 6” x 8 ½” Liner Length/Size: 250 m (820 ft) of 7” Liner. Well Type: 3D, horizontal Averaged ROP: 17m/hr (56 ft/hr) Drilled distance: 250 m (820 ft) Max. Inclination: 92°
40
The next step…? •
Dual position option
© 2015 Baker Hughes Incorporated. All Rights Reserved.
Phase 1 development – Q4 2015, Dual position with ‘retractable’ Pilot BHA Phase 2 development – 2017, One Trip system, Drill Run Liner and Cement 41
Modular System Example – Penta Combo BHA
SoundTrak
MagTrak
CCN
TesTrak
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BCPM
Modular Motor
42
ORD
LithoTrak
OnTrak / AziTrak
CoPilot
AutoTrak
Baker Hughes Formation Evaluation Portfolio
© 2015 Baker Hughes Incorporated. All Rights Reserved.
• • • • • • • • • • •
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OnTrak™ – Resistivity, gamma imaging, dynamics AziTrak™ – Deep azimuthal resistivity VisiTrak ™ – Extra Deep Azimuthal Resistivity ZoneTrak™ – Resistivity & Gamma Ray at bit StarTrak™ – High definition electrical imaging LithoTrak™ – Porosity, imaging, caliper, Pe SoundTrak™ – Advanced acoustic logging TesTrak™ – Formation pressure testing FASTrak™ – Fluid Analysis and Sampling MagTrak™ – LWD magnetic resonance logging SeismicTrak™ - Seismic While Drilling
Formation Evaluation Service Expansion at Baker Hughes VisiTrak AutoTrak eXact SureTrak AutoTrak Curve FASTrak SeismicTrak OnTrak 175 ZoneTrak AutoTrak eXpress Azimuthal Caliper Azimuthal Propagation Resistivity Wired Pipe BCPM II DeepTrak StarTrak
MPR
© 2015 Baker Hughes Incorporated. All Rights Reserved.
Triple Combo
MagTrak Sara II Co-Pilot TesTrak LithoTrak SoundTrak X-treme AutoTrak
Resistivity Gamma Teleco MWD
1975
44
Directional Gamma
1980
1985
1990
1995
2000
2005
2010
2015
Telemetry
Risk Mitigation Cost Reduction Evaluation
High Definition LWD Electrical Imaging
• Probe Base Systems NaviTrak (Discrete Pulse) TeleTrak (Discrete Pulse) EMTrak (Electromagnetic)
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• Collar Based Systems BCPM - (Discrete Pulse) BCPM II – (Discrete Pulse & Continuous Wave) Wired Pipe Wired Pipe BCPM2 45
Telemetry
Mud-Pulse Telemetry – Signal Types • Cone Valve Mud Pulser (BCPM, NaviTrak)
Discrete pulses Low frequency signal < 20 Hz Max. data rates of 6 bps
Discrete 1
0
1
0
1
0
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• Oscillating Shear Valve Mud Pulser (BCPM2)
Discrete pulses & continuous waves Low and high frequency signal < 60 Hz Max. data rate of 40 bps
46
PSK CW 1
0
1
OnTrak High Definition LWD Electrical Imaging
© 2015 Baker Hughes Incorporated. All Rights Reserved.
• Base tool for all services Directional Temperature Vibration / Stick Slip Annulus & Bore Pressure Battery for Flow Off Measurement Dual Azimuthal Gamma Ray Multiple Propagation Resistivity 2MHz Phase 400kHz Attenuation 4 Transmitters & 2 Receivers 8 Compensated Curves 47
Risk Mitigation Cost Reduction Evaluation
AziTrak High Definition LWD Electrical Imaging
© 2015 Baker Hughes Incorporated. All Rights Reserved.
• • • •
Deep reading Azimuthal Resistivity OnTrak with orthogonal receiver Direction & distance to bed boundaries (up to 17ft / 5m) Reservoir Navigation Service
T
48
R
Risk Mitigation Cost Reduction Evaluation
AziTrak
Risk Mitigation Cost Reduction Evaluation
High Definition LWD Electrical Imaging Drilled above (>32ft TVD) planned well path
Implement lateral & TVD geosteering decision
Dip in well = KOP for pilot hole
Tracking very close to roof down to TVD limit
TD in roof – very shallow dip
Model surface curtain
Up Down
APR image GR image
Distance to Bed (%)
Significant difference between planned and drilled wellpaths – average 23ft above plan
D istance to B ed
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> 14ft Signal amplitude 12 - 14ft 10 - 12ft
Drilled on average 7ft TVD below Top UCS
8 - 10ft 6 - 8ft 4 - 6ft
Achieved 98% N:G
2 - 4ft Resistivity 0-2ft
Completion interval ~ 5000ft MD
shale GR 0.0
5.0
10.0
15.0
20.0
25.0
30.0
Percentage of Lateral (%)
49
Lateral C44
Lateral C44z
Well came on production above the P90 estimates
VisiTrak - Extra Deep Azimuthal Resistivity High Definition LWD Electrical Imaging
• Based on proven DeepTrak and AziTrak technologies.
• Orthogonal transmitter array allows detection of multiple bed boundaries at up to 30 m (20kHz and 50kHz)
© 2015 Baker Hughes Incorporated. All Rights Reserved.
• Applications Quantifying reserves / confirming fluid contacts Increased depth of detection when landing wells. Identifying multiple boundaries, remote sands, additional reservoir levels. Understanding gross reservoir architecture. Detecting changes in reservoir thickness. Maximising reservoir contact. 50
Risk Mitigation Cost Reduction Evaluation
© 2015 Baker Hughes Incorporated. All Rights Reserved.
6 ¾“ VisiTrak Downhole system
51
Depth of Detection MPR Technologies
OnTrak ‐ 9 ft Non‐Azimuthal DeepTrak ‐ 50 ft
AziTrak ‐ 17 ft © 2015 Baker Hughes Incorporated. All Rights Reserved.
Azimuthal VisiTrak ‐ 100 ft
0 52
50 100 Maximum depth of detection (ft)
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VisiTrak – Extra Deep Azimuthal Resistivity
10 Ohmm Reservoir to 1 Ohmm Boundary 53
Extra Deep Azimuthal Resistivity (EDAR)
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High Definition LWD Electrical Imaging
54
Risk Mitigation Cost Reduction Evaluation
ZoneTrak / ZoneTrak G High Definition LWD Electrical Imaging
• Resistivity & Gamma Ray Geostopping Tool Casing point selection Core point selection Geological interpretation with seismic correlation Salt drilling applications – exit and entry • Oil & Water Based Mud © 2015 Baker Hughes Incorporated. All Rights Reserved.
• 4 ¾” Gamma Ray integrated into 4 ¾” AutoTrak
55
Risk Mitigation Cost Reduction Evaluation
ZoneTrak – Resistivity at Bit - Geostopping
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Formation Change !!! 21 ft
56 © 2009 Baker Hughes Incorporated. All Rights Reserved.
StarTrak High Definition LWD Electrical Imaging
• High resolution resistivity imager 120 sectors in memory / 16, 32 or 64 sectors realtime 0.25 inch x 0.25 inch pixel size • Applications Wellbore Placement Structural dip and dip azimuth for steering
Reservoir Characterization © 2015 Baker Hughes Incorporated. All Rights Reserved.
Bedding, Faults & Fractures
Wellbore Integrity (NPT) Breakouts and drilling induced fractures ECD management 57
Risk Mitigation Cost Reduction Evaluation
LithoTrak High Definition LWD Electrical Imaging
• Services Bulk Density (Azimuthal) Neutron Porosity Caliper (Azimuthal) Photoelectric Effect (Azimuthal)
© 2015 Baker Hughes Incorporated. All Rights Reserved.
• Applications Identification of gas filled porosity Structural characterisation & Reservoir Navigation Borehole size, shape & orientation Synthetic seismograms
58
Risk Mitigation Cost Reduction Evaluation
Images
Risk Mitigation Cost Reduction Evaluation
High Definition LWD Electrical Imaging
OnTrak/AziTrak Gamma Ray Image
structural bedding
© 2015 Baker Hughes Incorporated. All Rights Reserved.
LithoTrak Bulk Density Image
StarTrak HR Electrical Image
59
thin bed detail
SoundTrak High Definition LWD Electrical Imaging
• Realtime compressional slowness (12, 11 & 4 kHz) Monopole measurement 40-190 μsec/ft • Post run shear slowness (8, 4, 3 & 2 kHz) Quadrupole measurement Shear in slow formations (90-520 μsec/ft)
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• Applications Pore Pressure Predication Synthetic Seismogram Porosity Indicator Rock Strength 60
Risk Mitigation Cost Reduction Evaluation
Monopole Dipole Quadrupole
TesTrak High Definition LWD Electrical Imaging
• Formation Pressure Tester SmarTest & SmartPad technology
© 2015 Baker Hughes Incorporated. All Rights Reserved.
• Applications Formation pressures Calibrate realtime PPP Control overbalance / ECD Near wellbore mobility Gas / Oil / Water contact identification Depletion monitoring Reservoir connectivity
61
Risk Mitigation Cost Reduction Evaluation
TesTrak Real-Time Information
4500
– Annulus Pressures – Formation Pressures
4000
Pressure [psi]
– Draw Down Pressures 3500
– Mobility (downhole FRA) – Quality Indicator
3000
Final Build Up Criteria FRA Correlation
2500 © 2015 Baker Hughes Incorporated. All Rights Reserved.
– Temperature Change 2000 90
110
130 Time [s]
62
150
170
– Tool Face
FASTrak High Definition LWD Electrical Imaging
• Downhole Fluid Analysis Temperature Density Viscosity Sound Speed Oil / Gas Ratio © 2015 Baker Hughes Incorporated. All Rights Reserved.
• Downhole Fluid Sampling Sixteen Nitrogen buffered samples in single phase tanks Sample over-pressurisation for preservation 63
Built on TesTrak & Wireline RCI technology
Risk Mitigation Cost Reduction Evaluation
LWD Sampling Exit to Wellbore Termination Module Sampling Tanks
Tank Modules 4 x 4 tanks
Sample Pressure Gauge Draw Down Pump Fluid Analyzer Quartz Pressure Gauge
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Pump and Analyzer Module
Sealing Element Power Module 64
Realtime Fluid Analysis
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3 3 3 3 3 3 3 3 3 3 3 3 3 4 4 3 3 3 3 4 4 3 3 3 3 3 4 4 5 5
65
Mud Filtrate Transition Zone Formation Fluid
1 1
250 600
350 700
2 2
275 627
375 754
3 3
225 659
375 643
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Contamination vs. Time
66
• Volumes and times matched
MagTrak
Risk Mitigation Cost Reduction Evaluation
High Definition LWD Electrical Imaging
• Magnetic Resonance While Drilling T2 Distribution realtime • Motion insensitive measurement due to: Stabilisation of the sensor Near zero magnetic field gradient – vibration tolerant Very short interecho time (TE)
© 2015 Baker Hughes Incorporated. All Rights Reserved.
• Applications
67
Where are the fluids?
– Porosity
What is the fluid type?
– Fluid Differentiation
How much is producible?
– Movable vs. Bound
How easy is it to produce?
– Permeability Index
MagTrak – Nuclear Magnetic Resonance (NMR)
T2 Distribution
Echo Amplitude
20
Porosity
MultiExponential
15
Decomposition
10 5
© 2015 Baker Hughes Incorporated. All Rights Reserved.
0
100
300 200 Time (ms)
Matrix Rock
400
500
Dry Clay
Partial Porosity
Echo Train
3 2 1 0 0.1
1
100 10 T2 (ms)
1000
Clay- Capillary Movable water bound bound Heavy Medium Light water water Oil Oil Oil
Volumetrics 68
T2 cutoffs
4
SeismicTrak High Definition LWD Electrical Imaging
• Checkshot measurement (CS) First arrival – Formation velocity • Vertical Seismic Profile (VSP) Near / below well seismic imaging • Applications © 2015 Baker Hughes Incorporated. All Rights Reserved.
Reduce seismic uncertainty Control parameters in high risk zones Overpressure / Depleted / Salt Rubble Zones Casing point selection Avoid unnecessary sidetracks Reduce operating costs 69
Risk Mitigation Cost Reduction Evaluation
SeismicTrak - Measurement Principle
TVD [m]
1st Break
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Time [ms]
Vertical Seismic Profiling – Checkshot – CS VSP
70
© 2011 HM
SeismicTrak
Risk Mitigation Cost Reduction Evaluation
High Definition LWD Electrical Imaging
© 2015 Baker Hughes Incorporated. All Rights Reserved.
VSP Upwaves
Corridor Synthetic Stack SdTkSeismogram
Look-Ahead
71
Surface Seismic
Time-Depth Pairs
BEACON High Definition LWD Electrical Imaging
• Remote Operations Centre
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Realtime monitoring & operations WellLink RT WellLink Data Services WellLink Performance 24/7 Technical Support Drilling Optimisation Reservoir Navigation Services
72
Risk Mitigation Cost Reduction Evaluation
© 2015 Baker Hughes Incorporated. All Rights Reserved.
Thank You
Questions
73