advanced wellbore stability model (wellstab-plus) wellbore stability model: (mechanical model, does...
TRANSCRIPT
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TP00-09 1
Advanced Wellbore Stability Model
(WELLSTAB-PLUS)
Dr. William C. Maurer
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TP00-09 2
DEA-139 Phase I
DEA Sponsor: MarathonDuration: 2 YearsStart Date: May 1, 2000End Date: April 30, 2002Participation Fee: $25,000/$35,000
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Typical Occurrences of WellboreInstability in Shales
soft, swelling shale
brittle-plastic shale
brittle shale
naturally fractured shale
strong rock unit
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Wellbore Stability Problems
High Torque and Drag
Bridging and Fill
Stuck Pipe
Directional Control Problem
Slow Penetration Rates
High Mud Costs
Cementing Failures and High Cost
Difficulty in Running and Interpreting Logs
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Effect of Borehole Pressures
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PW PW
smax smax
smin smin
High Support Pressure Low Support Pressure
Effect of Mud Support Pressureon Rock Yielding
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Rock Failure
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Rock Failure Mechanisms
PLASTICBRITTLE
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Rock Yielding around WellboresLaboratory Tests
Rawlings et al, 1993
Isotropic Stresses Anisotropic Stresses
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Change In Near-Wellbore StressesCaused by Drilling
sV (overburden)
sHmin
sHmax sHmin
sHmax
Pw (hydrostatic)
Before DrillingIn-situ stress state
After DrillingLower stress within wellbore
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Stress Concentration around an Open Wellbore
Pw
Po
sHmin
sHmax
szsq
sq
sr
sz
sr
s
r
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Strength vs StressIdentifying the Onset of Rock Yielding
Shear
Str
ess
sr´
Effective Compressive Stress
Stable Stress State
sq´
sr´
Shear
Str
ess
sr´
Effective Compressive Stress
Unstable Stress State
sq´
sr´
sq´
MinStress
MaxStress
sq´
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Effect of Pore Fluid Saturation
POROUS ROCKSOLID ROCK
Pf = Fluid Pressure
so=szso=sz+pf
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Effective Stresses Partioningof Total Stress between
Mineral Grains and Pore Fluids
Po s
s
s´ = s - a Pos´ - effective stress
s - total stressPo - pore pressure
a - Biot Coefficient
( 1 for weak, porous rocks)
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Effective Rock Stress
sz= s o - pf
so = Overburden Stress
sz = Matrix Stress
pf = Pore Fluid Pressure
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Effect of Near-WellborePore Pressure Changeon Effective Stresses
Sh
ear
Str
ess
No Yield
Yield
Effective Compressive Stress
sr´ sq´sr´ sq´
Po increase
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TP00-09 20
MEI Wellbore Stability Model:(mechanical model, does not include chemical effects)
Linear elastic model (BP)
Linear elastic model (Halliburton)
Elastoplastic Model (Exxon)
Pressure Dependent Young’s Modulus Model(Elf)
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TP00-09 21
Mathematical Algorithms
Dr Martin Chenervert (Un. Texas)
Dr. Fersheed Mody (Baroid)
Jay Simpson (OGS)
Dr. Manohar Lal (Amoco)
Dr. Ching Yew (Un. Texas)
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TP00-09 22
Stress State on Deviated Wellbore
s3
s2sz sr
tqzbq
tzq
sq
a
s1
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TP00-09 23
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(BP)Linear Elastic Model
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TP00-09 26
(Halliburton)Linear Elastic Model
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TP00-09 28
(Exxon)Elastoplastic Model
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TP00-09 33
(Elf)Pressure Dependent
Young’s Modulus
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TP00-09 35
Shale Borehole Stability TestsDarley, 1969
DIESELDISTILLED WATER
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TP00-09 36
Montmorillonite Swelling PressurePowers, 1967
80,000
60,000
40,000
20,000
04th 3rd 2nd 1st
5000
4000
3000
2000
1000
0
SW
ELLIN
G P
RESSU
RE, psi
kg/c
m2
LAYERS OF CRYSTALLINE WATER
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TP00-09 37
Shale Water AdsorptionChenevert, 1970
0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80 0.90 1.00
5
4
3
2
1
0
WEIG
HT %
WATER
WATER ACTIVITY - aW
DESORPTION
ADSORPTION
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TP00-09 38
Shale Swelling TestsChenevert, 1970
TIME - HOURS
LIN
EAR S
WELLIN
G -
%
.01 0.1 1.0 10
0.4
0.3
0.2
0.1
0
-0.1
1.00
0.910.880.840.75
0.25
Activity of Internal Phase
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TP00-09 39
Effect of K+Ions on Shale SwellingBaroid, 1975
Ca ++
K+
K+
K+
Na+
Cs+
Na+
Ca++
Li+
K+
Rb+
Cs+
Na+
Mg++
Na+
10A°
Na+
--
--
-
--
-
-
-
-- -
-
-
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TP00-09 41
North Sea Speeton Shale SpecimenExposed at Zero DP to Drilling Fluid
Drilling Fluid:
Ionic Water-Base
(CaCl2 Brine)
Activity = 0.78
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TP00-09 42
North Sea Speeton Shale SpecimenExposed at Zero DP to Drilling Fluid
Drilling Fluid:
Oil-Base Emulsion
(Oil with CaCl2 Brine)
Activity = 0.78
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TP00-09 43
North Sea Speeton Shale Specimen
Exposed at Zero DP to Drilling Fluid
Drilling Fluid:
Non-Ionic Water-Base
(Methyl Glucoside in
Fresh Water)
Activity = 0.78
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TP00-09 44
Principle Mechanisms DrivingFlow of Water and Solute
Into/Out of Shales
Force
Flow
Fluid(water)
Solute(ions)
Hydraulic Gradient (Pw Po)Chemical Potential
Gradient (Amud Ashale)
HydraulicDiffusion
(Darcy´s Law)
Advection Diffusion(Fick´s Law)
ChemicalOsmosis
H2O
H2O H2O
H2Ot1
t2
t3
P
r
Other Driving Forces: Electrical Potential GradientTemperature Gradient
H2O H2O
H2O H2O
H2OH2O
H2O
+ -
-
-
+
+
+
-
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TP00-09 45
Osmotic Flow of Water throughIdeal Semi-Permeable Membrane
Ideal Semipermeable Membrane- permeable to water- impermeable to dissolved
molecules or ions
Water flow directionHigh concentration
of dissolved moleculesor ions ( = Low Aw )
Low concentrationof dissolved molecules
or ions ( = High Aw )
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TP00-09 49
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TP00-09 50
Limitations of Existing Models
Do not handle shale hydration
Very complex
Input data not available
Limited field verification
Cannot field calibrate
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TP00-09 51
Mathematical Algorithms
Dr Martin Chenervert (Un. Texas)
Dr. Fersheed Mody (Baroid)
Jay Simpson (OGS)
Dr. Manohar Lal (Amoco)
Dr. Ching Yew (Un. Texas)
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TP00-09 52
Mechanical/Chemical Property Input
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TP00-09 53
Help Information as Clicking Question Mark
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TP00-09 54
Pore Pressure Input/Predict
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TP00-09 55
Pore Pressure Predictionvia Interval Transit Time Log Data
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TP00-09 56
In-Situ Stresses Input/Predict
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TP00-09 57
Correlation to DetermineHorizontal Stresses
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TP00-09 58
Output Windows
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TP00-09 59
Safe Mud Weight vs Well Inclination
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Safe Mud Weight Distribution by Azimuth
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TP00-09 62
Near-Wellbore Stresses Distribution
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TP00-09 63
Mohr Diagram
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TP00-09 64
Wellbore Stress Distribution
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TP00-09 65
Propagation of Swelling Pressure
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TP00-09 68
Too large inclination
Wellbore Stability Design (continued)
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TP00-09 69
Wellbore Stability Design (continued)
Decrease inclination
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TP00-09 70
Wellbore Stability Design (continued)
Too high mud weight
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TP00-09 71
Wellbore Stability Design (continued)
Decrease mud weight
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TP00-09 72
Not enough salinity
Wellbore Stability Design (continued)
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TP00-09 73
Increase salinity
Wellbore Stability Design (continued)
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TP00-09 74
Wellbore Stability Design(through Mud Weight-Salinity diagram)
Too low mud weight
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TP00-09 75
Wellbore Stability Design (continued)
Increase mud weight
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TP00-09 76
Wellbore Stability Design (continued)
Not enough salinity
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TP00-09 77
Increase salinity
Wellbore Stability Design (continued)
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TP00-09 78
Wellbore Stability Design (continued)
Low Value Membrane Efficiency
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TP00-09 79
Wellbore Stability Design (continued)
High Value Membrane Efficiency
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TP00-09 80
Field Calibration
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TP00-09 81
Field Calibration (continued)
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TP00-09 86
Project Tasks
Distribute Wellbore Stability Model (WELLSTAB)
Develop Enhanced Model (WELLSTAB-PLUS)
Add time dependent feature to model
Hold workshops
Conduct field verification tests
Write technical reports
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TP00-09 87
Field Verification Goals
Determine model accuracy
Improve mathematical algorithms
Field calibrate model
Make models more user-friendly
Convert wellbore stability from an art into a science
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TP00-09 89
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TP00-09 90