fluid analysis and sampling while drilling fastrak · pdf filefluid analysis and sampling...
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Fluid Analysis and Sampling While Drilling
Don Rundle
Sales & Account Manager – Australasia
© 2010 Baker Hughes Incorporated. All Rights Reserved.
FASTrak
Agenda
• LWD Fluid Analysis Sampling & Testing
• 6 ¾” Schematic Description
• Service Specifications
• Field Testing Summary
• Summary
Provides a Solution to these issues / challenges:
• Compartmentalization• Ambiguous gradients / Thin beds• Sample Contamination Monitoring• Distinguishing between WBM and formation water• Optimizing sampling requirements• Accurate ECD management• Acquiring formation samples in ERD or Horizontal wells
LWD Fluid Analysis Sampling and Testing
Fluid Sampling
• Representative and minimal contamination• Provide info on production potential of reservoir• Information on design and development of
production facilities• Information on completion & development costs
Formation Pressure Testing
• Information of fluid dynamics within reservoir• Fluid Mobility• Pressure gradients – fluid type and density• Help Predict the productivity of zone• Safety and Drilling Optimization – Control
Overbalance/ECD
• Density, Viscosity, Refractive Index and Soundspeed• GOR and Compressibility• Real-time Clean up Monitoring• Fluid Typing
Downhole Fluid Characterization
LWD Fluid Analysis Sampling and Testing
© 2011 Baker Hughes Incorporated. All Rights Reserved.
Bit
StarTrak
(STK)
BCPM
LithoTrak
(ORD)
LithoTrak
(CCN)
OnTrak
(OTK)
MagTrak
(MTK)
Steerable
Stabilizer
Modular
Flex
Stabilizer
Modular
Stabilizer
Modular
Flex
StabilizerResistivity, Gamma,
DirectionalHigh Speed Telemetry
Caliper CorrectedNeutron
Optimized RotationalDensity
ModularStabilizer
Formation Pressure + Mobility + Fluid Analysis +Sampling
LWD Sampling & Testing
Electrical ResistivityImage
NMR,T2 Distribution
LWD Bottom Hole Assembly
FASTrak
6 ¾” O.D. Tool Schematic
Power Module
Pump andAnalyzer Module
Tank ModulesUp to 4 tanks
TerminationModule
Pump (Draw Down & Pump Thru)
Quartz Pressure Gauge
Sealing Element
Sampling Tanks
Exit to Wellbore& Fluid Analyzer
Fluid Analyzer
Sample Pressure Gauge
6 ¾” O.D. Service Specifications
• Hole Size Range
– Ideal for 8½” to 9½”
– 10” for horizontal hole or 11¾” if tool centralized in vertical hole
• Environmental
– Max Temperature: 150°C continuous & 165°C Survival
– Max Pressure: 25,000 psi
• Pump Capability
– Max Flowrate: 25 cc/s & 12.5 cc/s
– Max Overbalance: 4300psi & 8700 psi
• Chemical Resistance
– All fluid lines H2S resistant
• Communication
– Standard two way communication via mud pulses while circulating
11.75”
10”
8
Fluid Sensor Measurements –Density and Viscosity
Piezo-Electric Tuning Fork Resonator
• In-situ fluid density
– Measurement range: 0.01 – 1.5 g/cc
– Accuracy better than: 0.01 g/cc
– Resolution: 0.001 g/cc
• In-situ fluid viscosity
– Measurement Range: 0.2 – 200 cP
– Accuracy: +/- 20 % of measured viscosityor +/- 0.2 cP, whichever is greater
– Resolution: 0.01 cP
Tuning Fork
9
Typical Values
Gas = 1.00 – 1.25
Water = 1.30 – 1.40
Oil = 1.33 – 1.55
Ideally suited for differentiating formation water from WBM
Fluid Sensor Measurements - Refractive Index
Acoustic Transducer
– Real-time Fluid Sound Speed
Measurement Range 900 – 1800 m/sec
Resolution better than 1 m/sec
– Live Fluid compressibility
From density and sound speed as k = 1 / (Rho_Live * Sound_Speed_Squared)
Acoustic Pulse Echoes and Sound Speed for Water
-0.6
-0.4
-0.2
0
0.2
0.4
0.6
-5 0 5 10 15 20
Time [microseconds]
Sig
na
lA
mp
litu
de
Pulse Echo 2
Pulse Echo 3
Pulse Echo 4
Within Near-Wall Pulse Echo 1
Sound Speed c = 2 (I.D.) / tt (Round-Trip Across I.D. of Tube)
Far-Wall Reflection
402
404
406
408
410
Trans-
ducer
PulseGenerator
Tube
FLUID
TUBE
WALL
Fluid Sensor Measurements - Sound Speed
– Highly correlated to GAS OIL RATIO
For a given Temperature, Pressure & Live Oil Density
Maintain reservoir fluidphase behavior
Minimum mud filtratecontamination
Zero loss of H2Sand CO2
Maintain Reservoir FluidSample Quality
PVT Data
• GOR
• Saturation pressure
• FVF
• Compositional Analysis
Prevents overestimating orunderestimating the completion,
maintenance, and productioncosts
Single Phase Sample Tank Technology
Floating Piston(Balanced against Hydrostatic)
Floating Piston
Nitrogen Charge
Mixing Ball
MP35N Alloy (inert to H2S and Mercaptans)
Single Phase Sample (>500 cm3)
Service Capabilities
• Accurate Pressure Testing
– Capabilities implemented such as SmarTestTM and SmartPadTM
• Pump Through Capability
– Intelligent controlled closed loop pumping
with SmartPumpTM
• In-Situ Fluid Analysis
– Real-time data transmission
– Density, Viscosity, Refractive Index & Soundspeed
– Compressibility & BubblePoint (Experimental)
• Controlled Sampling and Continuous Monitoring
– Controlled pumping, overpressure and preservation
• Single Phase Sampling Technology
– Max Volume: 450cc - 830cc depending on N2 compensation
– Transportable: D.O.T. and Canadian Permit
– Advanced Optical Cylinder: non-invasive well site validation
• Continuous Circulation to Prevent Stuck Pipe
• Activate Pressure Test
• Select Pump Control
• Activate Sampling Command
• Real Time Pressure Information
• Real Time Fluid Analysis
• Real Time Sampling Information
Operations - Tool Communication
Challenges for LWD Sampling and Testing
• Measurement environment– Sealing efficiency
• Two pad sizes and shapes available, 95% sealing efficiency - SmartPadTM
– Wide range of formation permeability• Intelligent variation of drawdown rate and volume implemented - SmarTestTM
– Tool plugging in soft formation• Avoided with patented tool design
• Telemetry– Insufficient for real-time transmission of full draw-down and build-up
data• “Intelligent” self-learning system required – SmarTestTM
• Mitigate Risk of Sticking– Concerns about getting stuck during extended pump out periods
• Continuous circulation during fluid analysis and pump out stage – SmartPumpTM
© 2010 Baker Hughes Incorporated. All Rights Reserved.15
FASTrak Differentiators - Controlled Closed LoopSystems
• SmarTest™– Smooth drawdown feature starts and stops the DD rate slowly and
accelerates to max DD rate to prevent plugging– Optimizes rate and volume of subsequent drawdowns based on initial
drawdown using FRA™– Time savings during pressure testing due to intelligent control system
within tool
• SmartPad™– Optimizes the pad pressure during a test station to initiate and
maintain sealing efficiency– Guarantees reliability and confidence during pressure testing
• SmartPump™– Optimization of pump out during sampling and fluid analysis– Option to pump out either pressure controlled or rate controlled– Guarantees pumping above bubblepoint to prevent sampling flashing
Pressure Testing and Sampling Process
• Pressure Test (pulse data after test)– perform standard TesTrak pressure test utilizing SmarTestTM and SmartPadTM
– measure formation pressure, calculate mobility, quality indicator– pulse data to surface
• Fluid Analysis during Pump Through (continuous pulsing)– monitor all measurement channels for clean up– Sensor data cycle every 10-45 seconds depending on pulser data rate– wait for sampling command
• Sampling Process (continuous pulsing)– fill 1+ x sample tanks– overpressure sample
• Uplink Sample Information (uplink)
– volume, overpressure, fluid ID data
Field Testing Summary
Operational Data
• Number of Field Tests: 6
• Circulating Hours: 642 hrs
• Drilling Hours: 259 hrs
• Pressure Tests: 94
• Samples: 34 (8 oil, 6 gas, 20 water)
• Liters Pumped: 890 Liters
• Pumping Time: 54 hrs
• Longest Pumpout time: 9.5 hrs
• Mud Types: OBM & WBM
Field testing conclusions:
• Pressure Testing quality is equivalent to TesTrak
• Single Phase Sampling such as capture and retrieval is equivalent to wireline withadvantages in utilization of smart pump capability and tank data while sampling
• Clean up monitoring easily detectable in miscible fluids
• Monitoring becomes increasingly more difficult in immiscible fluids especially with gas
• Enhanced optics capability will be incorporated late 2012 / early 2013© 2010 Baker Hughes Incorporated. All Rights Reserved.17
• Low level contamination samples can be obtained with FASTrak
• The sooner the sample is taken after drilling, the less pump out time isrequired for a representative sample
• Establish good communication with customer early in the planningstage to fully understand customer objectives as well as BHIobjectives for the project
• Continue applying lessons learned to enhance the capabilities of theservice
Lessons Learned
Summary
• Build on TesTrak® Experience
– SmartPadTM, closed-loop system
– SmarTestTM, optimized testing
– SmartPumpTM, High Accurate Pump Control
– Downhole Analysis and Optimization
Summary
• Advantages of taking Samples While Drilling
– Shorter Pumpout Time due to Less Invasion
– Reduced Sample Acquisition Costs
– Reduced Risk and NPT
– Ability to take Samples in ERD or Highly Deviated Wells
Questions?