OptiDrillReal-time drilling intelligence service
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
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
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
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.
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
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
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.
*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