OptiDrill
Real-time drilling intelligence service
OptiDrill
Real-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.
Applications
Benefits
■■
Risk mitigation
■■
■■
Drilling performance improvement
■■
■■
Wellbore quality enhancement
Reduce BHA failures
Identify and mitigate poor hole cleaning and sticking
pipe tendencies
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
■■
Improve ROP by maximizing drilling efficiency
●●
estimation of weight on reamer
■■
Extend bit runs by preserving cutting structures
●●
continuous calculation of borehole friction factors
■■
Manage borehole tortuosity to aid casing running
●●
estimation of wellbore curvature from bending moment
■■
Optimize BHA design and bit selection
●●
plugged-nozzle and drillstring washout quick event detection
■■
Evaluate drilling technology performance
■■
Rigsite dashboard with integrated data display
■■
Validate and calibrate drilling models
■■
While-drilling monitoring, analysis, and recommendations from remote experts
■■
Continuous recording of low- and high-frequency data for postrun analysis
Quantify risk and manage downhole conditions
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.
Mitigating shock and vibration
to maximize drilling efficiency
The 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.
A
MOTION
BENDING (30 min)
100
G
DIN
BHA
STALL
STICK
SLIP
EN
1,000
ft.lbf
B
0
VIBRATION AMPLITUDE (30 min)
AXIAL
Severe Backward Whirl
Advice: Stop and restart with lower surface RPM
BIT
HOLE
TVD
4,549.07 ft.
4,549.07 ft.
4,354.67 ft.
B
WEIGHT TRANSFER (1,000 lbf)
MOTION
Surface
BENDING (30 min)
Downhole
10
BHA
STALL
20
1,000
ft.lbf
Surface
STICK
SLIP
Downhole
0
6
9.5
10
ECD/MWin (lbm/gal)
12
EN
DIN
0
TORQUE TRANSFER (1,000 ft.lbf)
D
LATERAL
100
G
C
B
0
VIBRATION AMPLITUDE (30 min)
AXIAL
ECD
MWTI
10.5
LATERAL
KEY TIME-BASED TRENDS (60 min)
10.5
TO
ECD
(lbm/gal)
E
ROP
10
10,000
167
DMSE
(psi)
ft/h
RPM
0
03:00
03:15
03:30
10.36
c/min
1,098
Incl (deg)
Azim (deg)
TVD (ft)
PRESSURE
FLOW
X,153.16
27.91
281.71
X,009.72
X,277.91
28.95
284.67
X,119.42
2,481
1,268
X,403.45
30.09
287.62
X,228.67
Sensor MD (ft)
lbm/gal
DIFF PRESSURE
119
03:45
RSIONAL
ECD
psi
psi
gal/min
A
Animation of downhole motions requiring
immediate attention to preserve the life
of the BHA
D
Quantification of weight and torque transfer
to enable early identification of abnormal
downhole conditions
B
Progression of vibration type and amplitude to
help modify drilling parameters and minimize
energy lost to vibrations
E
C
Guidance to aid mitigation
Calculation of equivalent circulation density (ECD)
and downhole mechanical specific energy (DMSE)
to understand hole cleaning and drilling
efficiency trends
TO
RSIONAL
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.
ROP
Weight
On Reamer
Gamma Ray
X,810
X,860
A
B
22:45
X,880
X,900
22:50
X,920
RTSTAT
22:55
X,910
X,960
ROP
BIT
ON BOTTOM
3089
X,038.98
Weight
On Reamer
Gamma Ray
23:00
X,810
ft
HOLE
TVD
X,038.98 ft
X,586.42 ft
0
GTF
-30
30
TF
168
X,980
X,860
-60
22:45
X,000
X,880
X,900
X,020
60
23:05
22:50
-90
X,920
0
ft/h
200 X,910
0
200
23:10
gAPI
0
22:55
90
20
1,000 lb
-120
X,960
120
23:00
X,980
-150
X,000
X,020
0
A
200 0
200
23:10
0
20
MD
(ft)
Incl
(deg)
Azim
(deg)
TVD
BR
TR
(ft)(deg/100ft)
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
Visualization of the location of the reamer
in the formation to help determine cause
of change in weight on reamer
150
180
23:05
B
DLS
AXIAL VIB
LATERAL VIB
TORSION VIB
LOW
LOW
LOW
Surface Weight
14
1,000
lbf
ECD
11.01
Bit Weight
3
1,000
lbf
ROP
lbm/
gal
111
Weight on Reamer
11
1,000
lbf
RPM
ft/h
82
c/min
Estimation of weight on reamer to increase the
life of the reamer through proactive management
of surface weight on bit and rpm
Wellbore Quality
Depth,
m
Scale BHA
and Caliper
Borehole
Image
EcoScope*†
Caliper
EcoScope
Density Image
Drilling Performance Improvement
Borehole Curvature
PowerDrive
Orbit*
Inclination
Pressure
Drilling
Efficiency
Drilling Mechanics and Downhole Forces
Pressures
Bending
Curvature
Risk Mitigation
Equivalent
Mud Weight
ROP
Weight
Torque and
Rotational Speed
Bending
Moment
Mechanical
Specific Energy
0 m/h 20
Dynamic
Bending
Delta
Mechanical
Specific
Energy
Borehole Friction Factor
Quick Event Detection Algorithms
Drilling Dynamics, Vibration Amplitudes, and Motions
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
Low Risk
Low Risk
Low Risk
Normal
Drilling
Normal
Drilling
Low Risk
Low Risk
Rotating
Friction Factor
Medium
Risk
Medium
Risk
Medium
Risk
Forward
Whirl
Medium
Risk
Medium
Risk
Medium
Risk
Plugged- Drillstring
Nozzle
Washout
Quick
Quick
Event
Event
Detection Detection
High Risk
High Risk
High Risk
Backward
Whirl
High Risk
High Risk
High Risk
Severe
Risk
Severe
Risk
Severe
Risk
Chaotic
Whirl
Severe
Risk
Severe
Risk
Severe
Risk
X,925
X,950
X,975
Absent
1.846
2.041
2.236
2.431
2.626
X,000
84 degree 88
Tool Bending
Curvature
0
g/cm3
6
º/30 m
Wellbore
Bending
Curvature
0
Flow Rate
ECD
1,000
galUS/min
Surface
WOB
Surface
Torque
13 lbm/galUS 16
0 lbf 20,000
0 ft.lbf 25,000
Standpipe
Pressure
Equivalent
Static Density
Avg
Downhole
WOB
Avg
Downhole
Torque
0 psi 4,000
13 lbm/galUS 16
Downhole
Differential
Pressure
Max.
Static Density
0
6
º/30 m
13 lbm/galUS 16
0 psi 4,000
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.
0 ft.lbf 25,000
0 lbf 20,000
0 ft.lbf 10,000
Max.
Downhole
WOB
Max.
Downhole
Torque
0 lbf 20,000
0 ft.lbf 10,000
13 lbm/galUS 16
Mud Weight In
Downhole
Mechanical
Specific Energy
0
Max.
Bending
Moment
0 ft.lbf 25,000
Min.
Static Density
Receive while-drilling
support from
interpretation experts
Avg
Bending
Moment
6,000,000
psi
Surface
Mechanical
Specific Energy
0
Surface rpm
0
0
7
0
7
0
7
0
3
–1
3
0
7
0
0.5
0
1
Probability
0 100
Pickup
Friction Factor
0
0
0.5
Slack-Off
Friction Factor
0.5
7
6,000,000
psi
0 c/min 200
13 lbm/galUS 16
Wellbore quality monitoring
Drilling performance improvement
Risk mitigation
To 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.
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.
Automated 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.
Improve future performance with postrun insight
Bending moment, up–down
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 recordedmode information include
■■
■■
■■
■■
validating and calibrating
drilling models
increasing knowledge
of formation drillability
otic
Cha
l
3
whir
2
optimizing BHA design
and bit selection
Be
nd
evaluating the performance
of drilling technology.
ing
mo
ar
irl
d wh
me
nt,
Forw
lef
t–r
igh
t
, min
Time
1
0
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.
250
Downhole rpm
Surface rpm
Rotational speed, rpm
200
150
100
50
0
18:26
18:27
18:28
18:29
18:30
18:31
18:32
18:33
18:34
18:35
Time
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.
18:36
Specifications
Mechanical
OptiDrill 675
OptiDrill 900
Nominal OD, in [cm]
Nominal ID, in [cm]
Max. OD (wearband), in [cm]
Length, ft [m]
Weight in air, lbm [kg]
Top thread connection
Bottom thread connection
Connection makeup torque, ft.lbf [N.m]
Connection yield torque, ft.lbf [N.m]
Mechanical Operations
6.89 [17.50]
4.80 [12.19]
7.78 [19.76]
9.84 [2.99]
903 [410]
5½ FH box
NC50 (41/2 IF) box
24,000 [32,539]
44,000 [59,655]
9.18 [23.31]
5.74 [14.57]
10.40 [26.41]
11.54 [3.51]
2,151 [976]
75/8 H90 box
75/8 Reg box
65,000 [88,128]
114,000 [154,563]
Max. temperature, degF [degC]
Max. shock (cycles), gn
302 [150]
250
302 [150]
250
Operating flow range, galUS/min
Max. operating pressure, psi [MPa]
Max. differential pressure, psi [MPa]
Pressure drop coefficient (C)†
Max. dogleg severity, °/100 ft
Rotating
Sliding
Max. overpull (tension), lbf
Max. weight on bit, lbf
Max. operating torque, ft.lbf [N.m]
Mud properties
Max. lost circulation material
Max. sand content, %
0 to 800
30,000 [206]
5,000 [34]
142,000
0 to 1,600
30,000 [206]
5,000 [34]
1,420,000
8
16
550,000
120,000,000/L2‡
24,000 [32,539]
6
12
930,000
550,000,000/L2‡
65,000 [88,128]
No limit
1
No limit
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
Digital signal processor
Processing time
Real-time telemetry
Downhole memory
Low frequency
High frequency
Power supply
19 channels at 10,000 Hz
180 Mflops
2-s window
Fully compatible with Orion II* data compression platform
and the IntelliServ® Network™
200 MB (250 h at 0.5 Hz [configurable])
1,500 MB (140 h at 50 Hz [fixed])
Low-power tool bus (LTB) and battery (75 h)
Power-saving mode
Trip-in time
Battery-saver time
Specifications
OptiDrill 675 Service
Measurement
Sensor
Real-Time
Range
Weight on bit†
Strain gauge
Torque†
Strain gauge
Bending moment†
Strain gauge
Vibration
Axial (x)
Lateral (y and z)
Rotational speed
Accelerometer
Annular and internal
pressure
Annular and internal
temperature
Continuous inclination
† Weight
Magnetometer
and gyroscope
Strain gauge
PT1000
Accelerometer
Real-Time
Resolution
±75,000 lbf
[±333,616 N]
±24,000 ft.lbf
[32,540 N.m]
61,000 ft.lbf
[82,705 N.m]
RecordedMode
Range
±93,000 lbf
[±413,684 N]
±30,000 ft.lbf
[40,675 N.m]
76,000 ft.lbf
[103,042 N.m]
0 to 31.75 gn
0 to 63.50 gn
–500 to
1,000 rpm
30,000 psi
0 to 31.75 gn
0 to 63.50 gn
–500 to
1,000 rpm
30,000 psi
–50 to
204 degC
0° to 180°
Real-Time
Processing
RecordedMode
Processing
2-s moving
window
2-s moving
window
2-s moving
window
Bandwidth
±3,000 lbf
[±13,344 N]
±1,000 ft.lbf
[±1,355 N.m]
±3,000 ft.lbf
[±4,067 N.m]
10-s moving
window
10-s moving
window
10-s moving
window
0.125 gn
0.25 gn
1 rpm
0.007 gn
0.007 gn
<1 rpm
30-s rms
30-s rms
2-s window
0.2 to 150 Hz
0.2 to 150 Hz
4 Hz
<1 psi
±0.25-gn rms 30-s rms
±0.25-gn rms 30-s rms
±5 rpm
30-s moving
window
±30 psi
1-s avg
1 psi
2-s window
200 Hz
–50 to 204 degC 1 degC
0.04 degC
±1 degC
1-s avg
2-s window
10 Hz
0° to 180°
0.1°
±0.4°
30-s avg
30-s window 10 Hz
Accuracy
Real-Time
Processing
Bandwidth
±4,000 lbf
[±17,792 N]
±2,000 ft.lbf
[±2,712 N.m]
±6,000 ft.lbf
[±8,135 N.m]
10-s moving
window
10-s moving
window
10-s moving
window
RecordedMode
Processing
2-s moving
window
2-s moving
window
2-s moving
window
30-s rms
30-s rms
2-s window
0.2 to 150 Hz
0.2 to 150 Hz
4 Hz
2-s window
200 Hz
10 Hz
0.1°
200 Hz
200 Hz
200 Hz
on bit, torque, and bending moment are compensated downhole for temperature, differential pressure, and hydrostatic pressure.
OptiDrill 900 Service
Measurement
Sensor
Real-Time
Range
Weight on bit†
Strain gauge
Torque†
Strain gauge
Bending moment†
Strain gauge
Vibration
Axial (x)
Lateral (y and z)
Rotational speed
Accelerometer
Annular and internal
pressure
Annular and internal
temperature
Continuous inclination
†Weight
Accuracy
300 lbf
[1,334 N]
100 ft.lbf
[135 N.m]
120 ft.lbf
[163 N.m]
RecordedMode
Resolution
50 lbf
[222 N]
7 ft.lbf
[9 N.m]
5 ft.lbf
[7 N.m]
Magnetometer
and gyroscope
Strain gauge
PT1000
Accelerometer
Real-Time
Resolution
±125,000 lbf
[±556,027 N]
±81,000 ft.lbf
[109,821 N.m]
132,000 ft.lbf
[178,968 N.m]
RecordedMode
Range
±156,000 lbf
[±693,922 N]
±101,000 ft.lbf
[136,938 N.m]
165,000 ft.lbf
[223,710 N.m]
500 lbf
[2,224 N]
320 ft.lbf
[434 N.m]
260 ft.lbf
[353 N.m]
RecordedMode
Resolution
80 lbf
[355 N]
17 ft.lbf
[23 N.m]
11 ft.lbf
[15 N.m]
0 to 31.75 gn
0 to 63.50 gn
–500 to
1,000 rpm
30,000 psi
0 to 31.75 gn
0 to 63.50 gn
–500 to
1,000 rpm
30,000 psi
0.125 gn
0.25 gn
1 rpm
0.007 gn
0.007 gn
<1 rpm
1 psi
<1 psi
±0.25-gn rms 30-s rms
±0.25-gn rms 30-s rms
±5 rpm
30-s moving
window
±30 psi
1-s avg
–50 to
204 degC
0° to 180°
–50 to 204 degC 1 degC
0.04 degC
±1 degC
1-s avg
2-s window
0° to 180°
0.1°
±0.4°
30-s avg
30-s window 10 Hz
0.1°
on bit, torque, and bending moment are compensated downhole for temperature, differential pressure, and hydrostatic pressure.
200 Hz
200 Hz
200 Hz
Find out more about the OptiDrill service
at slb.com/OptiDrill
Animation
Watch 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 Report
OptiDrill service improves BHA
reliability to help an operator
drill to section TD in one run
in deepwater Gulf of Mexico.
slb.com/OptiDrill
*Mark of Schlumberger
Other 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