john macpherson - stick slip presentation
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John Macpherson - Stick Slip PresentationTRANSCRIPT
1
The Science of Stick-Slip
IADC Stick-Slip Mitigation WorkshopJuly 15, 2010
John MacphersonBaker Hughes Inc.
2
BendingBendingBending
WhirlWhirlWhirlLateral Vibration
Stick-SlipStickStick--SlipSlipTorsional Vibration
Bit BounceBit BounceBit BounceAxial Vibration
Jarring (impact)Jarring (impact)Jarring (impact)
Three Modes of Vibration
Torsional Vibrations
•Drillstring is a Spring-Mass System (Torsional Pendulum)
• Torsional Oscillation frequency is the first natural torsional frequency for the drillstring System
• Frequency is very low, usually less than 1/2 Hz, for a drillstring of any length.
Torsional Oscillation Period
• Analytic Calculation: Bailey J.J., and Finnie I., "An Analytical Study of Drill-String Vibration", Trans. ASME, May 1960, pp 122-128
•• Empirical:Empirical: period of oscillation increases by 2 seconds per 1,000m of 5” pipe (Dufeyte and Henneuse, 1991, IADC/SPE 21945)
0
2
4
6
8
10
12
14
0 5000 10000 15000 20000 25000 30000
6-3/4 x 200 ft BHA8-1/4 x 200 ft BHA
Drillstring Length, feetDrillstring Length, feet
Tors
iona
l Osc
illatio
n P
erio
d, s
econ
dsTo
rsio
nal O
scilla
tion
Per
iod,
sec
onds
Torsional VibrationsB
it R
otat
ion
Rat
e
A B C
• A – Increase RPM, B – Torsional Oscillations, C – Stick-Slip (period = 4.5s)
Smooth rotation Torsional Oscillations Stick-Slip
Stick-Slip: bit rotation periodically stalls during continuous surface rotation.StickStick--Slip: bit rotation periodically stalls during continuous surfaceSlip: bit rotation periodically stalls during continuous surface rotation.rotation.
Time (secs)
Field Example, downhole rotation measurements
Severe Stick Slip
200 250 300 350 400
600
400
200
0
Time (seconds)
0
10
20
30
50
100
150
kN.m
kN
Stick periods 24 s rotation periods 2.5s
Maximum DRPM 645; Surface 70
-165 RPM for 1.4s
Increase RPM
Vertical Well (2.5 deg), about 10,300 feet, measurements 8 feet above bit.
Stick-Slip Example Roller Cone Bit
15
10
0
5
-5400300
200
100
0
-100100
50
0
320 330 340 350 360 370
Wei
ght,
kNTo
rque
, kN
.mR
PM
Elapsed Time, seconds
• Downhole Rotation Rate• Stick-slip period = 3.3 seconds
Modeling: Stick-Slip Visualization
Downhole torsional oscillations and stick-slip behavior are visible as periodic torque fluctuations on surface
Downhole torsional oscillations and stickDownhole torsional oscillations and stick--slip behavior are visible slip behavior are visible as periodic torque fluctuations on surfaceas periodic torque fluctuations on surface
•• Drillstring SimulationDrillstring Simulation– Finite Element Model– Arbitrary curved and
straight boreholes– String can move freely in
wellbore– Wall contact penalty
formulation– Friction during drillstring-
wall contact – Torque on bit from a
coupled bit model
Bit and Drillstring Coupled Modeling
• Bit interaction with rock (rock properties) important
• Validated with high frequency downhole measurements
• “Falling friction” characteristic• Stribeck type bit-friction model
0 50 100 150 2000
3000
6000
9000
Rotational Speed [RPM]
Torq
ue o
n Bi
t [N
m]
0 5 10 15 200
3000
6000
9000
Torq
ue o
n Bi
t [N
m]
T ime [s]
0 5 10 15 200
100
200
Time [s]
Rota
tiona
l Spe
ed [R
PM]
MeasurementSimulation
BBB nnT 91.49658.100608.5231
Reckmann, Jogi, Herbig, 2007, Reckmann, Jogi, Herbig, 2007, ““USING DYNAMICS MEASUREMENTS WHILE DRILLING TO DETECT LITHOLOGY CUSING DYNAMICS MEASUREMENTS WHILE DRILLING TO DETECT LITHOLOGY CHANGES HANGES AND TO MODEL DRILLING DYNAMICSAND TO MODEL DRILLING DYNAMICS””, paper 29710, OMAE, 26, paper 29710, OMAE, 26thth International ConferenceInternational Conference
Comparison of measurements and simulation for the Stribeck type bit
model
Comparison of measurements and Comparison of measurements and simulation for the Stribeck type bit simulation for the Stribeck type bit
model model
• Stick-slip likely when operating in region of “falling friction”• Increase RPM to reduce likelihood of stick-slip
Bit and Drillstring Coupled Modeling
Stick-Slip Likely Stick-Slip Unlikely
Reckmann, Jogi, Herbig, 2007, Reckmann, Jogi, Herbig, 2007, ““USING DYNAMICS MEASUREMENTS WHILE DRILLING TO DETECT LITHOLOGY CUSING DYNAMICS MEASUREMENTS WHILE DRILLING TO DETECT LITHOLOGY CHANGES HANGES AND TO MODEL DRILLING DYNAMICSAND TO MODEL DRILLING DYNAMICS””, paper 29710, OMAE, 26, paper 29710, OMAE, 26thth International ConferenceInternational Conference
Measuring Stick-Slip Downhole: Stick-Slip Index
RPM
RPMRPMSSIavg2
minmax
RPM
A B C
SSI 0 0.1 0.1 inc to 1.0 > 1.0
• A – Increase RPM, B – Torsional Oscillations, C – Stick-Slip (period = 4.5s)
SSI is encoded in a few bits and transmitted to surfaceSSI is encoded in a few bits and transmitted to surfaceSSI is encoded in a few bits and transmitted to surface
CoPilot Memory Depth LogCoPilot Memory Depth Log
Surf WOBSurf WOBklbfklbf
DH WOBDH WOBklbfklbf
Surf TRQSurf TRQftlbftlb
DH TRQDH TRQftlbftlb
Surf RPMSurf RPM
Max RPMMax RPMRPMRPM
Avg RPMAvg RPMRPMRPM
Min RPMMin RPMRPMRPM
S Slip SeverityS Slip Severity
Tangential VibTangential Vibgravitygravity
Bit BounceBit Bounce
Axial VibAxial Vibgravitygravity
Whirl SeverityWhirl Severity
Lateral VibLateral Vibgravitygravity
Stick-Slip SeverityMin, Max,
Average RPM
DH and SURF Torque
DH and SURF WOB
Axial Vibration Severity
Lateral Vib Severity
Example MWD Memory Log showing wellbore friction and stick-slip
Example MWD Memory Log showing Example MWD Memory Log showing wellbore friction and stickwellbore friction and stick--slipslip
Stick-Slip: Relationship to Failure
•• MWD ComponentsMWD Components– 2010 study, IADC/SPE 127413– Significant relationship to MWD tool failures:
1. Lateral Acceleration Peak Energy2. Lateral Acceleration 1s RMS Energy3. Cumulative RPM Variation (revolutions)4. Cumulative Backward Whirl5. Cumulative Stick-Slip Index
•• PDC BitsPDC Bits– May be damaged during stick-slip– Center of rotation off the center of the bit– Cutters on some part of the bit move
backwards for some portion of a revolution– Chipped and damaged cutters
Stick-Slip: Recognition and Control•• Measurement DownholeMeasurement Downhole
– Measure rotation rate of drillstring– Magnetometers and/or centripetal acceleration– Bit periodically stalls (MWD diagnostic transmission)
•• Measurement on SurfaceMeasurement on Surface– Rotary torque & rotary speed– Large periodic fluctuations in torque
•• StickStick--Slip ControlSlip Control– Manual (follow flow charts)
1. Reduce WOB, increase RPM2. Stop drilling, restart with decreased WOB, increased RPM
– Automatic• Soft-torque stick-slip control systems• Modifies drive speed control to reduce torsional fluctuations
– Downhole / Autonomous• Torque control Subs
0 2Stick-Slip Index
0
20
40
60
Late
ral V
ibra
tion
(g)
1
Downhole Data Distribution for 219 MWD runsDownhole Data Distribution for 219 MWD runs
Fully Developed StickFully Developed Stick--SlipSlip
1
SlidingSliding
Reckmann etal 2010, Reckmann etal 2010, ““MWD Failure Rates Due to Drilling DynamicsMWD Failure Rates Due to Drilling Dynamics””, IADC/SPE 127413, IADC/SPE 127413
Stick-Slip and Lateral Vibrations
Contours showing data sets with average ROP in excess of 45 ft/hr, overlaid on colored surface defined by Stick-Slip Index and Maximum Lateral Acceleration.
0 2Stick-Slip Index
0
20
40
60la
tera
l Vib
ratio
n (g
)
SlidingSliding Fully Developed StickFully Developed Stick--SlipSlip
High ROPLow LateralsModerate SSI
High ROPMod LateralsLow SSI
Downhole Data Distribution for 219 MWD runsDownhole Data Distribution for 219 MWD runs
Stick-Slip, Lateral Vibrations and ROP
Reckmann etal 2010, Reckmann etal 2010, ““MWD Failure Rates Due to Drilling DynamicsMWD Failure Rates Due to Drilling Dynamics””, IADC/SPE 127413, IADC/SPE 127413
The Science of Stick-Slip – Conclusions
– Torsional drillstring behavior includes both torsional oscillations and stick- slip. In stick-slip the bit periodically stalls in rotation
– Stick-slip is detrimental to drill bits, and sustained stick-slip can be damaging to MWD components
– Stick-slip behavior is relatively well understood, can be modeled, and can be recognized both downhole and on surface while drilling
– Stick-slip behavior can be mitigated manually, automatically, and using downhole subs
– Removing torsional oscillations from the system will result in the BHA being susceptible to high lateral vibrations, which could result in rapid MWD failure