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?