project: de-fe0001836: numerical modeling of geomechanical … · 2013-08-22 · project:...
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Project: DE-FE0001836:
Numerical modeling of
geomechanical processes related to
CO2 injection within generic
reservoirs
Andreas Eckert & Runar Nygaard
Missouri University of Science & Technology
U.S. Department of Energy
National Energy Technology Laboratory
Carbon Storage R&D Project Review Meeting
Developing the Technologies and Building the
Infrastructure for CO2 Storage
August 21-23, 2012
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Presentation Outline
• Objectives, Benefits and Outcomes
• Technical status: Project summary
– Teaching
– Reservoir scale (Geomechanics & Fluid flow
simulation)
– Borehole scale (Wellbore integrity & wellbore
trajectory planning)
• Conclusions
• Appendix
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Benefit to the Program
• Program goals being addressed.
– Develop technologies that will support industries’
ability to predict storage capacity in geologic
formations to within 30 percent.
• Project benefits statement: – This research & training project is training graduate students to develop
numerical models of anticline formations for sequestration sites in order
to assess geomechanical risks as well as critical wellbore placement
and wellbore integrity. The results give a more thorough understanding
of how reservoir geometry affects wellbore stability, formation and cap
rock stability and thus facilitates future site selection. This technology
contributes to the Carbon Storage Program’s effort that will support
industries’ ability to predict storage capacity in geologic formations to
within 30 percent.
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Project Overview: Goals and Objectives
Goals & Objectives
• Train graduate students to develop
multi-scale numerical models (finite
element models and finite difference
models.
• Assess geomechanical risks (with
respect to how fluid pressure induces
rock deformation): reservoir and cap
rock stability, wellbore stability,
wellbore trajectory optimization.
Success criteria
• 400 level graduate course on
“Advanced Finite Element
Analysis with CO2 applications”
– participating students enrolled
& passed.
• Milestones, quarterly progress
reports, presentations and
publications.
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Technical Approach:
Methodology
• Multi-scale modeling
to study influences of
large scale models
on borehole
– Optimal wellbore
trajectory
– Optimal wellbore
design
More stable
wellbore?
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σ’1 (40.1 MPa)σ’3 (21.3 MPa)
σ’1 (44.1 MPa)
σ’3 (21.5 MPa)
Stress in the Anticline
• Antiformal structures are prime injection
targets
– Stress state is altered by the geometry
– Varying the geometry will alter the injectivity
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Pre-injection geomechanical
risk assessment: Objectives
• Develop of reservoir scale finite element
model of generic anticline structures
• Perform critical pore pressure (CPP) analysis
• Determine the influence of certain geometric
and geologic parameters on CPP
– Anticline Wavelength
– Anticline Amplitude
– Stress Regime
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Workflow
Altair Hypermesh®
to build geometries
Input boundary and
initial conditions
Abaqus/Standard®
to process finite
element models
Matlab® for data
processing
Microsoft Excel®
to analyze data
Abaqus/Viewer®
to view results
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Model Setup
• Constructed using
Altair HyperMesh™
2500m
6000m
3000
m
g z
x
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Reservoir-Caprock System
• Calculations of critical pore pressure done
for reservoir and caprock layers
Top Shale
Top Sandstone
Caprock
Reservoir
Bottom Shale
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Varying Anticline Wavelength
3000
m
1500m Wavelength
750m Wavelength
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Varying Anticline Amplitude
50
m
100
m
150
m
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Far-Field Stress Regimes
• Extensional Regime:
– Uniaxial strain assumption used to calculate
horizontal stress
• Strike-slip Regime:
– σH=1.2σv, σh=0.8σv
• Compressional Regime:
– σH=1.5σv, σh=1.25σv
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Pre-Injection Critical Pore Pressure
• Maximum allowable pore pressure based
on Mohr Coulomb Failure model
• At failure:
• Pcrit,intact:
• Pcrit,reactivated:
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Graphically Representing CPP
• Shortest distance along the normal stress
axis from the Mohr circle to the failure
envelope
CPP
Intact
σ σ’1 σ’3
τ
CPP Reactivated
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Results
• Results were plotted at three locations in
the anticline; crest, limb, and valley
• In general the crest of the formation is
most likely to have reactivation of fractures
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CPP vs Anticline Wavelength
• Lowest values for CPP at
crest for all stress regimes
• Shorter wavelength has
slightly higher CPP overall
– Lowest value is 2.5 MPa
Extension
Strike-Slip
Compression
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CPP vs Anticline Amplitude
• Crest is the most vulnerable
• Differences are most notable in
strike-slip and compression
regimes
• The larger amplitude tends to
exhibit larger CPP
Extension
Strike-Slip
Compression
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Necessity of 3D Models
• Analytical solutions are available that
predict the CPP based on known far-field
stresses
• The addition of complex geometry
invalidates those solutions
ΔPcrit,r (MPa) for various stress regimes
Extension Strike-slip Compression
Analytical solution for
horizontally layered basin 0 6.7 24.0
Numerical anticline model 5.9 11.4 13.1
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Locations and type of fractures
• Shear fractures would be developed in the
crest of the structure
• Tensile failure likely in the limbs
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CPP vs Friction between layers
• Lower COF has higher
heterogeneity in each layer
• Lowest COF shows biggest
difference between
reservoir and cap rock
• Lowest value is 4 MPa in
the 0.1 COF case
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Conclusions
• Three dimensional models are required
when the geometry is complex
• Shorter wavelength sustains higher pore
pressure
• For reactivation of shear fractures, the
strike-slip regimes has the highest CPP
• Relevance of geometric parameters is
different for each stress regime
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Wellbore stability: objectives
• Wellbore trajectory
optimization in progress
– Find safe mud weight window
• Optimal wellbore design
– Sensitivity study on modeling
parameters after CO2 injection
in progress
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Wellbore trajectory optimization
• Conventional wellbore
trajectory planning:
– Use Andersonian
stresses (SV, SH, Sh)
– Determine safe mud
weight window for
inclined wells
• Advantage of numerical
approach:
– Full stress tensor used as
input
– Not limited to Andersonian
state of stress
– Implementation of full virtual
well path
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[Zoback, 2007]
-10 -5 0 5 10 15 20 25 30 35 40-1500
-1000
-500
0
Pressure (MPa)
Depth
(m
)
'1500wl100mA100m3ext Crest'
Pmax
Pmin
Pp
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Wellbore trajectory planning
• Calculate type I inclined well
paths
– Vertical section, inclined
section, inclination angle
• Extract stress results from
FE model locations
• Calculate mud weight
window (for all cases from
the 3D reservoir scale
model)
• Results analysis in progress 26
28003000
32003400
36003800
40004200
4400
-800
-600
-400
-200
0
200
400
600
800
-1500
-1000
-500
0
Depth
(m
)
2800
3000
3200
3400
3600
3800
4000
4200
4400
-800-600
-400-200
0200
400600
800
-1500
-1000
-500
0
Depth
(m
)
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Coupled model
• Coupling module developed in Project DE-
FE0001132
• Run simulations: in progress
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Accomplishments to Date
– 4 Graduate students (3 MSc, 1PhD) trained in numerical
modeling of CO2 sequestration applications.
– Pre-injection geomechanical risk assessment
(calculation of maximum reservoir pressure) for generic
anticline settings completed.
– Detailed sensitivity analysis on stress regime, anticline
geometry, inter-bedding friction completed.
– Numerical model parameter optimization of wellbore
scale model completed.
– Optimal wellbore placement and trajectory planning for
wellbore stability analysis completed.
– CO2 injection simulation: Detailed sensitivity analysis on
flow boundary conditions and anticline geometry
completed.
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Summary
– Geologic setting (geometry) strongly affects
state of stress and associated geomechanical
risks. Models should not be simplified to
horizontally layered basin.
– Prevailing stress regime and inter-bedding
friction important input parameters for FEM
models.
– Fluid flow boundary conditions: crucial
parameter
– Lessons Learned
– Future Plans 29
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Organization Chart: Project
team
• PIs: Dr. Andreas Eckert; Dr. Runar Nygaard
• Graduate students
– MingYen Lee: MSc student; Petroleum
Engineering; graduated;
– Matthew Paradeis: MSc student; Petroleum
Engineering; graduated;
– Nevan Himmelberg: MSc student; Petroleum
Engineering;
– Amin Amirlatifi: PhD student; Petroleum
Engineering;
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Project Participants
• Dr. Andreas Eckert: PI
• Dr. Runar Nygaard: Co-PI
• MingYen Lee (ML): PhD student;
Petroleum Engineering
• Matthew Paradeis (MP): Masters student;
PE
• Nevan Himmelberg (NH): Undergraduate
assistant
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Gantt chart
Technical Tasks Year 1 Year 2 Year 3 Year 4
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1
1.0 Project Management, Planning and Reporting
2.0 Introduction and literature research
2.1 CO2 sequestration lecture
2.2 Literature research
3.0 2D Finite Element study
3.1 2D model construction and result verification
3.2 Result analysis of CO2 injection related pore pressure modeling
3.3 Re-modeling of fractured regions
4.0 Initial model generation of 3D borehole section
5.0 3D FE study of reservoir settings
5.1 Pre-stressed 3D model
5.2 CO2 injection related pore pressure modeling
6.0 3D wellbore placement & integrity analysis
6.1 Integrate BCs for optimal drilling location
6.2 Integrate BCs for optimal wellbore integrity
7.0 Documentation of results and final report to DOE
Project reports AR AR FR
AR: Annual report; FR: Final report
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Bibliography
Peer reviewed publications:
– Lee, M., Eckert A., and Nygaard R., 2011. Mesh optimization for finite element
models of wellbore stress analysis. Presented at the 45th US Rock
Mechanics/Geomechanics Symposium, San Francisco, CA, June 26-29, 2011.
– Paradeis, M. A., Eckert A., and Liu, X, 2012. Influences of Anticline Reservoir
Geometry on Critical Pore Pressures Associated with CO2 Sequestration. Presented
at the 46th US Rock Mechanics/Geomechanics Symposium, Chicago, CA, June 24-
27, 2012.
– Amirlatifi, A., Eckert A., Nygaard R., Bai B., Liu, X, and Paradeis M.A., 2012. Role of
Geometrical Influences of CO2 Sequestration in Anticlines. Presented at the 46th US
Rock Mechanics/Geomechanics Symposium, Chicago, CA, June 24-27, 2012.
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