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Page 1: OptiDrill - slb.com/media/Files/drilling/brochures/mwd/optidrill... · Optimize BHA design and bit selection Evaluate drilling technology performance Validate and calibrate drilling

OptiDrillReal-time drilling intelligence service

Page 2: OptiDrill - slb.com/media/Files/drilling/brochures/mwd/optidrill... · Optimize BHA design and bit selection Evaluate drilling technology performance Validate and calibrate drilling

OptiDrillReal-time drilling intelligence service

Manage downhole conditions and BHA dynamics with the OptiDrill* real-time drilling intelligence service. Integrated downhole and surface data provide actionable information on a rigsite display to mitigate risk and increase efficiency. These data are simultaneously interpreted by remote experts, who collaborate with the drilling team to improve performance.

Features ■ Downhole sub with 19 drilling mechanics and dynamics sensors ■ Real-time drilling answers, including

● downhole detection of whirl, bit bounce, and stick/slip motions and severity ● estimation of weight on reamer ● continuous calculation of borehole friction factors ● estimation of wellbore curvature from bending moment ● plugged-nozzle and drillstring washout quick event detection

■ Rigsite dashboard with integrated data display ■ While-drilling monitoring, analysis, and recommendations from remote experts ■ Continuous recording of low- and high-frequency data for postrun analysis

Applications ■ Risk mitigation ■ Drilling performance improvement ■ Wellbore quality enhancement

Benefits ■ Reduce BHA failures ■ Identify and mitigate poor hole cleaning and sticking

pipe tendencies ■ Improve ROP by maximizing drilling efficiency ■ Extend bit runs by preserving cutting structures ■ Manage borehole tortuosity to aid casing running ■ Optimize BHA design and bit selection ■ Evaluate drilling technology performance ■ Validate and calibrate drilling models

Page 3: OptiDrill - slb.com/media/Files/drilling/brochures/mwd/optidrill... · Optimize BHA design and bit selection Evaluate drilling technology performance Validate and calibrate drilling

0 10 20

03:00 03:15 03:30 03:45

0 6 12

9.5 10 10.5

10.5

1010,000

0

MOTION BENDING (30 min)

VIBRATION AMPLITUDE (30 min)

LATERAL

AXIAL

BHASTALL

STICKSLIP

100

1,000ft.lbf

0

B

EN

DIN

G

T O R S I O N A L

4,549.07 ft. ft. ft.4,549.07 4,354.67

BIT HOLE TVD

E

D

C

A

B

C

D

E

Mitigating shock and vibration to maximize drilling efficiencyThe OptiDrill service detects whirl, bit bounce, and stick/slip motions and their severity. In the example below, a large-hole BHA is crossing a formation boundary and experiencing severe backward whirl. This motion is detected downhole by the OptiDrill service’s sub and displayed in real time with a recommended mitigation on the rigsite display.

Quantify risk and manage downhole conditions

Quantification of weight and torque transfer to enable early identification of abnormal downhole conditions

Calculation of equivalent circulation density (ECD) and downhole mechanical specific energy (DMSE) to understand hole cleaning and drilling efficiency trends

Animation of downhole motions requiring immediate attention to preserve the life of the BHA

Progression of vibration type and amplitude to help modify drilling parameters and minimize energy lost to vibrations

Guidance to aid mitigation

The OptiDrill service helps you mitigate risk and improve drilling performance through early detection of ROP limiters and drilling hazards. Real-time motion detection and weight-on-reamer information allow the rigsite team to proactively manage parameters. The OptiDrill service provides the driller with immediate guidance on how to mitigate severe downhole dynamics. Early intervention typically lessens the severity of an event, protecting the BHA and extending the length of the bit run.

Severe Backward WhirlAdvice: Stop and restart with lower surface RPM

Surface

Downhole

WEIGHT TRANSFER (1,000 lbf)

TORQUE TRANSFER (1,000 ft.lbf)

ECD/MWin (lbm/gal)

KEY TIME-BASED TRENDS (60 min)

Surface

Downhole

ECD

MWTI

ECD (lbm/gal)

DMSE (psi)

Sensor MD (ft) Incl (deg) Azim (deg) TVD (ft)

X,153.16 27.91 281.71 X,009.72

X,277.91 28.95 284.67 X,119.42

X,403.45 30.09 287.62 X,228.67

ROP ECD

167 ft/h 10.36 lbm/gal

RPM DIFF PRESSURE

119 c/min 1,098 psi

PRESSURE FLOW

2,481 psi 1,268 gal/min

MOTION BENDING (30 min)

VIBRATION AMPLITUDE (30 min)

LATERAL

AXIAL

BHASTALL

STICKSLIP

100

1,000ft.lbf

0

B

EN

DIN

G

T O R S I O N A L

A

B

Page 4: OptiDrill - slb.com/media/Files/drilling/brochures/mwd/optidrill... · Optimize BHA design and bit selection Evaluate drilling technology performance Validate and calibrate drilling

AXIAL VIB

LOW

LATERAL VIB

LOW

TORSION VIB

LOW

RTSTATON BOTTOM

3089

ROP Gamma Ray Weight On Reamer

22:45

22:50

22:55

23:00

23:05

23:10

X,810

X,860

X,880

X,900

X,920

X,910

X,960

X,980

X,000

X,020

0 20200200 0 0

0

-30 30

-60 60

120

150

180

-150

-120

90-90

Estimation of weight on reamer to increase the life of the reamer through proactive management of surface weight on bit and rpm

Visualization of the location of the reamer in the formation to help determine cause of change in weight on reamer

A B

Managing drilling parameters to extend the life of the reamer In reaming-while-drilling applications, the OptiDrill service continuously estimates weight on reamer by combining downhole measurements from below the reamer with surface measurements. In the example below, the BHA is passing through formations with significant strength contrasts. The driller is using the estimated weight on reamer and a visualization of the reamer location to proactively manage surface weight to keep the weight on reamer within an acceptable range.

X,038.98 ft X,038.98 ft X,586.42 ft

GTF TF 168

14

11.01

3

111

11

82

MWD X,527.99 34.68 299.01 X,108.19 -0.11 0.26 0.18

MWD X,655.55 34.67 298.56 X,273.10 -0.01 -0.36 0.20

MWD X,782.69 35.44 296.12 X,377.18 0.61 -1.92 1.26

MWD X,907.44 35.22 295.09 X,478.96 -0.18 -0.82 0.51

MWD X,992.46 35.29 295.15

RSS X,030.52 35.65 298.15

MD Incl Azim TVD BR TR DLS (ft) (deg) (deg) (ft) (deg/100ft)

BIT HOLE TVD

Surface Weight

ECD

Bit Weight

ROP

Weight on Reamer

RPM

1,000 lbf

lbm/ gal ft/h c/min

1,000 lbf

1,000 lbf

ROP Gamma Ray WeightOn Reamer

22:45

22:50

22:55

23:00

23:05

23:10

X,810

X,860

X,880

X,900

X,920

X,910

X,960

X,980

X,000

X,020

0 20200200 0 0

1,000 lbgAPIft/h

BA

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X,925

Scale BHA and Caliper Drilling Dynamics, Vibration Amplitudes, and Motions

0 70 70 70 7 0 7 –1 30 3

Low RiskLow RiskNormalDrilling

NormalDrillingLow RiskLow RiskLow Risk

High RiskHigh RiskHigh RiskBackwardWhirl

High RiskHigh RiskHigh Risk

MediumRisk

MediumRisk

MediumRisk

ForwardWhirl

MediumRisk

MediumRisk

MediumRisk

SevereRisk

SevereRisk

SevereRisk

ChaoticWhirl

SevereRisk

SevereRisk

SevereRisk

Borehole Friction FactorQuick Event Detection Algorithms

0 1

0 0.5

0 0.5

DrillstringWashout

QuickEvent

Detection

Probability

Plugged-NozzleQuick Event

Detection

RotatingFriction Factor

Slack-OffFriction Factor

PickupFriction Factor

0 0.5

Borehole Curvature

Tool BendingCurvature

Wellbore Bending

Curvature

0 6º/30 m

0 6º/30 m

84 degree 88

DrillingEfficiency

DeltaMechanical

SpecificEnergy

DownholeMechanical

Specific Energy

SurfaceMechanical

Specific Energy

0 6,000,000psi

0 6,000,000psi

Pressures

ECD

EquivalentStatic Density

Max.Static Density

Min.Static Density

Mud Weight In

Flow Rate

StandpipePressure

DownholeDifferential

Pressure

0 psi 4,000

0 psi 4,000

13 lbm/galUS 16

13 lbm/galUS 16

13 lbm/galUS 16

13 lbm/galUS 16

13 lbm/galUS 16

0 1,000galUS/min

Drilling Mechanics and Downhole Forces

Max.BendingMoment

AvgBendingMoment

AvgDownhole

Torque

AvgDownhole

WOB

Max.Downhole

Torque

Max.Downhole

WOB

DynamicBending

SurfaceTorque

Surface rpm

Surface WOB

0 ft.lbf 25,000

0 ft.lbf 25,000

0 m/h 20

0 ft.lbf 25,0000 lbf 20,000

0 ft.lbf 10,0000 lbf 20,000

0 ft.lbf 10,0000 lbf 20,000

0 c/min 200

BoreholeImage

Abse

nt1.

846

2.04

12.

236

2.43

12.

626

Wellbore Quality Risk MitigationDrilling Performance Improvement

EcoScope*†

CaliperDepth,

mEcoScope

Density Image

g/cm3

PowerDrive Orbit*

Inclination

Bending Curvature Pressure Equivalent

Mud Weight ROP Weight Torque and Rotational Speed

Bending Moment

Mechanical Specific Energy

rms Axial Vibration Severity

Bit-Bounce Severity

rms Lateral Vibration Severity

Whirl Type Whirl Severity

rms Torsional Vibration Severity

Stick /Slip Severity

Borehole Friction Factor

Quick Event Detection

X,000

X,950

X,975

0 100

Receive while-drillingsupport from interpretation experts

Risk mitigationAutomated quick event detection algorithms monitor for indications of plugged bit nozzles and drillstring washout.

Using surface and downhole measurements, the OptiDrill service continuously calculates torque and drag to provide borehole friction factors for early identification of sticking pipe tendencies.

Drilling performance improvement In addition to the rigsite visualization of drilling efficiency information and immediate guidance for mitigating BHA dynamics, remote interpretations are shared with the rigsite team to help identify optimal surface parameters.

Wellbore quality monitoringTo aid casing running, the service detects microdogleg and spiraling using bending moment data. Real-time wellbore quality data logs enable evaluation of the stability of the borehole over time.

Data from the OptiDrill service is transmitted to surface for use by the rigsite team and for interpretation by remote experts. The experts collaborate with the drilling team to reduce risk, improve drilling performance, and manage borehole quality.

Page 6: OptiDrill - slb.com/media/Files/drilling/brochures/mwd/optidrill... · Optimize BHA design and bit selection Evaluate drilling technology performance Validate and calibrate drilling

Bending moment, left–right

Time, min

0

1

2

3Be

ndin

g m

omen

t, up

–dow

n

A BHA with a reamer entered forward whirl motions and then chaotic whirl motions, which were detected and mitigated in real time. Postrun analysis revealed that the whirling motions occurred when the reamer entered an unstable formation. This information will be used while drilling future wells planned in this formation.

18:26 18:27 18:28 18:29 18:30 18:31 18:32 18:33 18:34 18:35 18:36

250

200

150

100

50

0

Time

Rota

tiona

l spe

ed, r

pm

Downhole rpm Surface rpm

Improve future performance with postrun insight

Chaotic whirl

The OptiDrill service records low- and high-frequency data, which are available for postrun analysis to evaluate drilling system performance. This information provides valuable input for the planning of future wells.

Key applications of this recorded- mode information include

■ validating and calibrating drilling models

■ increasing knowledge of formation drillability

■ optimizing BHA design and bit selection

■ evaluating the performance of drilling technology.

A postrun visualization of surface and downhole rpm was used to evaluate the effectiveness of a surface control system to minimize stick/slip. The chart was created using high-resolution (50-Hz) data recorded by the OptiDrill service.

Forward whirl

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Specifications

Mechanical OptiDrill 675 OptiDrill 900

Nominal OD, in [cm] 6.89 [17.50] 9.18 [23.31]

Nominal ID, in [cm] 4.80 [12.19] 5.74 [14.57]

Max. OD (wearband), in [cm] 7.78 [19.76] 10.40 [26.41]

Length, ft [m] 9.84 [2.99] 11.54 [3.51]

Weight in air, lbm [kg] 903 [410] 2,151 [976]Top thread connection 5½ FH box 75/8 H90 box

Bottom thread connection NC50 (41/2 IF) box 75/8 Reg box

Connection makeup torque, ft.lbf [N.m] 24,000 [32,539] 65,000 [88,128]

Connection yield torque, ft.lbf [N.m] 44,000 [59,655] 114,000 [154,563]

Mechanical Operations

Max. temperature, degF [degC] 302 [150] 302 [150]

Max. shock (cycles), gn 250 250

Operating flow range, galUS/min 0 to 800 0 to 1,600

Max. operating pressure, psi [MPa] 30,000 [206] 30,000 [206]

Max. differential pressure, psi [MPa] 5,000 [34] 5,000 [34]

Pressure drop coefficient (C)† 142,000 1,420,000

Max. dogleg severity, °/100 ftRotating 8 6

Sliding 16 12

Max. overpull (tension), lbf 550,000 930,000

Max. weight on bit, lbf 120,000,000/L2‡ 550,000,000/L2‡

Max. operating torque, ft.lbf [N.m] 24,000 [32,539] 65,000 [88,128]

Mud propertiesMax. lost circulation material No limit No limit

Max. sand content, % 1 1† Pressure drop, psi = [(mud weight, lbm/galUS) × (flow, galUS/min)2] /C. ‡ L = the distance (ft) from the bottom of the stabilizer blades immediately above the OptiDrill service sub to the top of the stabilizer blades immediately below the OptiDrill service sub.

Data Acquisition and Processing

Sample rate 19 channels at 10,000 Hz

Digital signal processor 180 Mflops

Processing time 2-s window

Real-time telemetry Fully compatible with Orion II* data compression platform and the IntelliServ® Network™

Downhole memoryLow frequency 200 MB (250 h at 0.5 Hz [configurable])

High frequency 1,500 MB (140 h at 50 Hz [fixed])

Power supply Low-power tool bus (LTB) and battery (75 h)Power-saving mode Trip-in time Battery-saver time

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Specifications

OptiDrill 675 ServiceMeasurement Sensor Real-Time

RangeRecorded-Mode Range

Real-Time Resolution

Recorded-Mode Resolution

Accuracy Real-Time Processing

Recorded-Mode Processing

Bandwidth

Weight on bit† Strain gauge ±75,000 lbf [±333,616 N]

±93,000 lbf [±413,684 N]

300 lbf [1,334 N]

50 lbf [222 N]

±3,000 lbf [±13,344 N]

10-s moving window

2-s moving window

200 Hz

Torque† Strain gauge ±24,000 ft.lbf [32,540 N.m]

±30,000 ft.lbf [40,675 N.m]

100 ft.lbf [135 N.m]

7 ft.lbf [9 N.m]

±1,000 ft.lbf [±1,355 N.m]

10-s moving window

2-s moving window

200 Hz

Bending moment† Strain gauge 61,000 ft.lbf [82,705 N.m]

76,000 ft.lbf [103,042 N.m]

120 ft.lbf [163 N.m]

5 ft.lbf [7 N.m]

±3,000 ft.lbf [±4,067 N.m]

10-s moving window

2-s moving window

200 Hz

Vibration Accelerometer

Axial (x) 0 to 31.75 gn 0 to 31.75 gn 0.125 gn 0.007 gn ±0.25-gn rms 30-s rms 30-s rms 0.2 to 150 Hz

Lateral (y and z) 0 to 63.50 gn 0 to 63.50 gn 0.25 gn 0.007 gn ±0.25-gn rms 30-s rms 30-s rms 0.2 to 150 Hz

Rotational speed Magnetometer and gyroscope

–500 to 1,000 rpm

–500 to 1,000 rpm

1 rpm <1 rpm ±5 rpm 30-s moving window

2-s window 4 Hz

Annular and internal pressure

Strain gauge 30,000 psi 30,000 psi 1 psi <1 psi ±30 psi 1-s avg 2-s window 200 Hz

Annular and internal temperature

PT1000 –50 to 204 degC

–50 to 204 degC 1 degC 0.04 degC ±1 degC 1-s avg 2-s window 10 Hz

Continuous inclination Accelerometer 0° to 180° 0° to 180° 0.1° 0.1° ±0.4° 30-s avg 30-s window 10 Hz†Weight on bit, torque, and bending moment are compensated downhole for temperature, differential pressure, and hydrostatic pressure.

OptiDrill 900 ServiceMeasurement Sensor Real-Time

RangeRecorded-Mode Range

Real-Time Resolution

Recorded-Mode Resolution

Accuracy Real-Time Processing

Recorded-Mode Processing

Bandwidth

Weight on bit† Strain gauge ±125,000 lbf [±556,027 N]

±156,000 lbf [±693,922 N]

500 lbf [2,224 N]

80 lbf [355 N]

±4,000 lbf [±17,792 N]

10-s moving window

2-s moving window

200 Hz

Torque† Strain gauge ±81,000 ft.lbf [109,821 N.m]

±101,000 ft.lbf [136,938 N.m]

320 ft.lbf [434 N.m]

17 ft.lbf [23 N.m]

±2,000 ft.lbf [±2,712 N.m]

10-s moving window

2-s moving window

200 Hz

Bending moment† Strain gauge 132,000 ft.lbf [178,968 N.m]

165,000 ft.lbf [223,710 N.m]

260 ft.lbf [353 N.m]

11 ft.lbf [15 N.m]

±6,000 ft.lbf [±8,135 N.m]

10-s moving window

2-s moving window

200 Hz

Vibration Accelerometer

Axial (x) 0 to 31.75 gn 0 to 31.75 gn 0.125 gn 0.007 gn ±0.25-gn rms 30-s rms 30-s rms 0.2 to 150 Hz

Lateral (y and z) 0 to 63.50 gn 0 to 63.50 gn 0.25 gn 0.007 gn ±0.25-gn rms 30-s rms 30-s rms 0.2 to 150 Hz

Rotational speed Magnetometer and gyroscope

–500 to 1,000 rpm

–500 to 1,000 rpm

1 rpm <1 rpm ±5 rpm 30-s moving window

2-s window 4 Hz

Annular and internal pressure

Strain gauge 30,000 psi 30,000 psi 1 psi <1 psi ±30 psi 1-s avg 2-s window 200 Hz

Annular and internal temperature

PT1000 –50 to 204 degC

–50 to 204 degC 1 degC 0.04 degC ±1 degC 1-s avg 2-s window 10 Hz

Continuous inclination Accelerometer 0° to 180° 0° to 180° 0.1° 0.1° ±0.4° 30-s avg 30-s window 10 Hz†Weight on bit, torque, and bending moment are compensated downhole for temperature, differential pressure, and hydrostatic pressure.

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*Mark of SchlumbergerOther company, product, and service names are the properties of their respective owners.†Japan Oil, Gas and Metals National Corporation (JOGMEC), formerly Japan National Oil Corporation (JNOC), and Schlumberger collaborated on a research project to develop LWD technology that reduces the need for traditional chemical sources. Designed around the pulsed neutron generator (PNG), EcoScope service uses technology that resulted from this collaboration. The PNG and the comprehensive suite of measurements in a single collar are key components of the EcoScope service that deliver game-changing LWD technology.Copyright © 2015 Schlumberger. All rights reserved. 14-DR-0183

Find out more about the OptiDrill service at slb.com/OptiDrill

AnimationWatch an animation that shows how the OptiDrill service provides actionable information to mitigate drilling risk and increase efficiency.

Case Study Total eliminates a planned bit run with OptiDrill service in a 17½-in section in the North Sea.

Tech ReportOptiDrill service improves BHA reliability to help an operator drill to section TD in one run in deepwater Gulf of Mexico.

slb.com/OptiDrill


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