Presentation at the Advanced Workshop for CO2 Storage, Mexico City, 26-27 August 2014

1. Gonzalo Zambrano, PhD, PEng
Research Associate
University of Alberta
Advanced Workshop for CO2 Storage
August 26-17, 2014
DF IPN ESIA Ticomán Auditorium
SUPPORTED BY:

2. Modeling CO2 Injection into Saline Aquifers
From Pore Space to Public
SUPPORTED BY:
Outreach
Research Activities on the Geological Storage of CO2

3. Major Research Areas
P.I.: Dr. Rick Chalaturnyk
 CARBON CAPTURE and STORAGE (CCS)
 Well Integrity
 Risk Assessment
 Reservoir-Geomechanical Processes (Cap
Rock Integrity, microseismic, ..)
 Constitutive Behavior
 Reservoir Surveillance (MMV, Closed-Loop)
 PETROLEUM GEOMECHANICS
◦ Role of Geomechanics in Thermal Recovery Processes (SAGD, CSS, etc.)
◦ Geomechanical Characterization of Bitumen Carbonates
 SURFACE MINING OF OIL SANDS
◦ Tailings Management (thickened tailings, paste, etc.)
◦ Constitutive Behavior of Oil Sands

4. Carbon Capture and Storage (CCS)
 IEA Weyburn CO2 Monitoring and Storage Project
◦ Phase 1 (2000-2004)
 Well Integrity
 Bounding Seal Integrity
 Performance Assessment/Mechanical Earth Model
◦ Final Phase (2007-2011)
 Theme Leader for Risk Assessment
 Well Integrity
 Reservoir Surveillance
 CSEMP (Alberta Research Council) - ECBM
◦ Geomechanics
◦ Reservoir Surveillance (tiltmeters)
 Penn West Pembina Cardium CO2 Monitoring Project
◦ Reservoir Surveillance
◦ Reservoir Geomechanics
 Simulations
 Experiments
 Aquistore
◦ Geomechanics
◦ Reservoir Surveillance / Well Integrity
◦ Risk Assessment

5. Research Team
PhD Research Projects:
Geological Storage:
Well Integrity Assessment Methodology for CCS
CBM/ECBM Reservoir Geomechanical Characterization
Deployment of Downhole Monitoring Technology
Reservoir-Geomechanical Simulations for CO2 Geological Storage
Risk Assessment Framework for CCS
Integrated Full Life-Cycle Analysis of Well Integrity
Influence of CO2 Drying on Formation Properties
Petroleum Geomechanics:
Numerical Investigation of Pressure Pulsing Theory
Role of Multiphysics Modelling for Reservoir Geomechanical
Problems
Res-Geom Processes for SMART Fields in SAGD
Accelerated SAGD Processes
Strength Mobilization in Stiff Clays and Weak Rocks
Reservoir-Geomechanical Simulations of Faulted Reservoir

6. Advancing Reservoir Geomechanics
Research for Unconventional Resources F-CMP.
GI.: DIRr. RCick Chalaturnyk

7. CSA Z741-12 (Future section of ISO for CCS)
Table of Contents
1 Scope
2 Reference publications
3 Definitions
4 Management systems
5 Site screening, selection, and
characterization
6 Risk management
7 Well infrastructure development
8 Monitoring and verification
9 Closure

8. Consideration of Project Life Cycle

9. CSA Z741-12 (Modelling)
“Site characterization — a detailed evaluation of one or more
candidate sites for CO2 storage identified in the screening and
selection phase of a CO2 storage project to confirm and refine
containment integrity, storage capacity, and injectivity estimates,
and to provide basic data for initial predictive modelling of fluid”
CSA Z741-12
5.5 Modelling for Characterization
5.5.2 Geological Static Model
5.5.3 Flow Modelling
5.5.4 Geochemical Modelling
5.5.5 Geomechanical Modelling
• Key modelling parameters
• Modelling outcomes

10. Modelling
Analytical Modelling
Advance Numerical
Modelling
Degree of Uncertainty
High
Low
Less More
Saline
Aquifers
“Modelling is heavily influenced by the quantity and
quality of the defining attributes of the system,
including the associated data” CSA-Z741
History
Match
?

11. Intensity Uncertainty (%)
Container
Domain
Above Container
Domain
Near Surface
Domain
Baseline
Mode
Operational
Mode
Environmental
Mode
Risk (%)
Time (logarithmic)
Monitoring
MMV
MMV
MMV ?

12. Initial Task List
 Detailed Site Characterization
 Geophysical Monitoring/Modelling
(synthetic seismogram)
 Geochemical Sampling and Analysis
 Reservoir Surveillance Wells
 Numerical Simulations

13. Complex Process Interactions

14. Building a Static Model – Structure &
Properties
Geophysics
Geology Geomechanic
s
Petrophysics
Mineralogy
Flow / Transport
Seismic
Well Correlation
Fault Modeling
Zonation and
Layering
Facies Modeling
Property Modeling
Model should include overburden
PETREL

15. CO2 Injection Dynamic Modelling
(History match)
Calibration on monitoring
measurements
CO2 Concentration in Water
Thermodynamics
Geochemistry
Thermal
Modeling
Geomechanics Simulator
Monitoring Data
Upscaling
Accurate description of fluid -fluid / fluid-rock
interactions
§Thermodynamics
§ Precipitation / dissolution reactions
§ Impact of CO2 purity
3D Full Compositional Flow
Simulator
ECLIPSE
CO2STORE/CMG

16. Why Geomechanics Important for
CCUS?

17. Failure Envelopes in Stress Space
• Link Static and Dynamic
Geomechanical Properties

18. Reservoir Injection Rate Capacity
GR GR GR GR GR GR GR
Approximate Injection Loc.
Regina:
Thick sand
packages
3000m
3100m
3200m
Precambrian

19. CO2 Saturation
Year 2 Year 4 Year 10
2000 T/d (Winnipeg and Lower
Deadwood)
Total: 1.5 Mtonne
2 km
2 km 2 km
Case 1: 2000 T/d (Winnipeg and Lower Deadwood)

20. Differential Pressure (MPa)
10 km
Year 2
Case 5: 2000 T/d (Full Interval)
Year 10
Year 20
Ambient P:
34 MPa (or 5000 psi)
10
1
0.1
MPa

21. Modelling
 fluid dynamics and reactive transport of
CO2 in geologic formations.
 realistic reservoir models for different
geologies and including reservoir
heterogeneities.
 trapping mechanisms
 risk assessment including all potential
pathways to the biosphere
 reservoir management strategies that
ensure storage security

22. Research Programs
 Well Integrity – From Operations to Abandonment to
Post-Closure
 Numerical Modelling of CO2 Storage to Support Long-
Term Liability Transfer of CO2 Geological Storage Sites
 Continuum/Discontinuum Modelling for Assessment of
Geomechanical Monitoring Technologies
 Constitutive Properties to Support Storage Site
Performance Predictions and Monitoring Program
Design
 Monitoring Technologies for In Situ Stress
Measurements

23. Research Programs
 Well Integrity – From Operations to Abandonment to
Post-Closure
 Numerical Modelling of CO2 Storage to Support Long-
Term Liability Transfer of CO2 Geological Storage Sites
 Continuum/Discontinuum Modelling for Assessment of
Geomechanical Monitoring Technologies
 Constitutive Properties to Support Storage Site
Performance Predictions and Monitoring Program
Design
 Monitoring Technologies for In Situ Stress
Measurements

24. Well Integrity
Blue Dots– randomly selected area
Yellow Dots – Pattern 1 Wells
Green Dots – Pattern 2 Wells
Brown Dots – Pattern 3 Wells
• The pre- and post- phases of the
performance assessment are a
necessity.
• The approach combined both
“real” field data (well files,
production data, etc.) and
analytical or numerical
simulations.

25. Weyburn Test Well: 101/08-06-006-13W2
 Vertical well drilled in 1957
 5.5 inch production casing
 Previously an oil producer
Prod. Csg. Cement
Mannville
1068 m
 Located at corner of CO2 flood area (Phase 1B)
 Suspended in June 2009
 Retainer set 5 m above perforations
 Sector bond log and multi-finger 1302 caliper m
were
run in November 2009; conditions looked good
Watrous
 Cement squeeze below retainer completed in
October 2010 (prior to cased-hole logging
program)
1439 m
CO2

26. Well Integrity: Field Testing Program
Modified coring tool:
 Direct confirmation of cement

27. Pressure transient test
confirms cement effectiveness
Field Testing
Program

28. Pressure Transient Testing of Cement
Sheath 1. Create two “slots”
~1.7 m apart
2. Isolate using packers.
3. Inject fluid into upper slot.
4. Monitor pressure response below middle packer.
5. Interpret system perm. from pressure-time data.
H
p
L. Watrous

32. Setup Coiled Tubing
Unit, Install PTT Tool

35. Run PTT Tests on Shallow,
Intermediate and Deep Intervals

36. Cement Behavior and Well
Abandonment Strategies
6000
5000
4000
3000
2000
1000
0
0 20 40 60 80 100 120
Time (min)
Respond Pressure (Pa)
Bad Cement & Sand Formation (8 Holes)
Applied Pressure / 1000
Bad Cement & Sandy Formation (10 Holes)
Bad Cement & Sandy Formation (12 Holes)
Bad Cement & Sandy Formation (14 Holes)
4500
4000
3500
3000
2500
2000
1500
1000
500
0
0 20 40 60 80 100 120
Time (min)
Respond Pressure (Pa)
Bad Cement & Sand Formation
Applied Pressure / 1000
Good Cement & Silt Formation
Intermediate Cement & Silt Formation
Good Cement & Sand Formation
Grinding Tools:
Cubic boron nitride
(CBN)
Splintered carbide
Annular Carbide Cutters:
Annular HSS Cutters:

37. Detailed Near-Well Modeling
Perforations at 1600mkb’s, 13 sh/m
L c
Tubing
Casing
Cardium Zone
PT#02
1611mkb
L c
Tubing
Casing
Upper
Cardium
Sandstone
Middle
Cardium
Sandstone
FRS#02
1622mkb
Perforations at 1300mkb’s, 17 sh/m
Tubing
Casing
Lc
Lea Park (Shale)
FRS#01
1301mkb
PT#01
1302mkb

38. Detailed Near-Well Modeling
FLAC (Version 4.00)
LEGEND
30-Aug-06 11:55
step 143
-1.750E-01 <x< 1.750E-01
-1.750E-01 <y< 1.750E-01
Grid plot
0 1E -1
0.125
0.075
0.025
-0.025
-0.075
-0.125
cement annulus
-0.125 -0.075 -0.025 0.025 0.075 0.125
JOB TITLE :
rock formation
steel casing

39. Cement Job
Zambrano, Zambrano, G. and Chalaturnyk, R. 2008 G. and Chalaturnyk, R. 2007

40. Measured Depth (m)
0
200
400
600
800
1000
1200
1400
1600
1650
Annulus Casing
0
1168
1190
1256
Brine, 1300.0 (kg/m3)
Preflush ..., 1000.5 (kg/m3)
Prefush f..., 1000.5 (kg/m3)
Slurry, 1760.0 (kg/m3)
Displace ..., 1000.5 (kg/m3)

41. Near-Wellbore – Numerical
Modelling
• Post-Evaluation of completion
• Evaluation near-wellbore environments
CFD – Near wellbore modelling
Near well bore modelling during Installation
- 3D geometry
-Transient problem (4D)
-Multiphase flow (Newtonian and Non-Neotonian fluids)

42. 3D Drawing
Pressure & Temperature
gauge
Pressure & Temperature
gauge
Fluid Recovery Port
Geophone

43. Meshing
Geophone
Fluid Recovery
Port
Pressure and
Temperature
gauge
Pressure and
Temperature
gauge

44. CFD animation
Plan view of
animation
CFD animation
Volume fraction
of cement
displacement

45. CFD – Outcomes

46. CFD – Outcomes

47. CFD – Outcomes
0.12
Integral quantity
I II
0.1
0.08
0.06
0.04
0.02
0
0 2 4 6 8 10
Area, m2
Time, s
III IV
Surface Area of ISVF 98%
Surface Area of ISVF 95%
Surface Area of ISVF 90%
[98%] 2.413x10-2
[95%] 6.146x10-3
[90%] 1.609x10-3
Nodes Elements
40,812 190,844

48. CFD – Outcomes
0.16
0.14
0.12
0.1
0.08
0.06
0.04
0.02
0
0 2 4 6 8 10
Area, m2
Time, s
Surface Area of ISVF 98%
Surface Area of ISVF 95%
Surface Area of ISVF 90%
[98%] 2.458x10-2
[95%] 6.093x10-3
[90%] 8.813x10-4
Nodes Elements
Patent P1396PC00 50,394 240,209

49. Penn West CO2-EOR Pilot
Penn West CO2-EOR Pilot

52. Pennwest CO2-EOR Pilot
6 Producers, and 2 injectors
PP22
100/7-11 well (the OBS Well)
II1
P1
102/7-11 well (the newly drilled production well)

53. Geology and Design Completion
Ground Surface 0
Ardley Coal 434
Knee Hill Tuff
494
506
1023
1291.4
1599
1619
1619.5
Edmonton
Belly River
Lea Park
Cardium Zone
Cardium Conglomerate
Upper Cardium Sandstone
Middle Cardium Sandstone
Lower Cardium Sandstone
1622
1630.5
1100
1120
1140
1160
1180
1200
1220
1240
1260
1280
1300
1320
1340
1360
1380
1400
1420
1440
1460
1480
1500
1520
1540
1560
1580
1600
1620
3 pairs of
pressure/
temperature
gauges
Completion Configuration for Obs Well (100/7-11-48-9W5)
All fluid sampling tubing, geophone cables and
gauge cables run to surface. From surface to
1200 mD filled with inhibited fluid (water). All
instrumentation strapped to 2 3/8 “ tubing string.
Cement Top at 1200 mD
Fluid Sampling Port #1
at 1301 mD. Port located within
Upper Lea Park zones where
porosity is ~ 7%
Two (2) pressure/temp.
gauges at 1302 mD.
Fluid Sampling Port #2
at 1622 mD. Port located
within Upper/Middle
Cardium SST
Two (2) pressure/temp.
gauges at 1610 mD. In
the middle of the Cardium
Zone.
Two (2) pressure/temp.
gauges at 1621 mD.
1637.2
8 Geophone String. Bottom phone
at 1640 mD and phone spacing is
20 m.
2 downhole
fluid sampling
ports
8 phone
Geophone
string
Shale

54. P
T
1303 Press2 1610 Press1 1620 Press1
1620 m
1303 Temp2 1610 Temp1 1620 Temp1
Sunday, February 27, 2005
24000
22000
20000
18000
16000
14000
60
55
50
45
40
35
Stopped pumping to maintain pressure
2/26/05 10:00:00 2/26/05 12:00:00 2/26/05 14:00:00 2/26/05 16:00:00 2/26/05 18:00:00
Pressure, kPa
Temperature, C
Time (m/d/y h:m:s)
Begin circulating
cement
Begin circulating
prewash fluid
Cement
circulation
finished
Started Closing
BOP Bags
Bags Finished
Closing
Pumping to pressure
up annulus started
Began bleeding off
annulus pressure
1303 m
P
T
Reservoir Pressure

55. Downhole Fluid Recovery System
Ground Surface
Ardley Coal
Knee Hill Tuff
Knee Hill Tuff
Belly River
Lea Park
Cardium Zone
Cardium Conglomerate
Upper Cardium Sandstone
Middle Cardium Sandstone
Lower Cardium Sandstone
Compleation Configuration for Obs Well (100/7-11-48-9W5)
1100
1100
1120
1140
1160
1180
1200
1220
1240
1260
1280
1300
1320
1340
1360
1380
1400
1420
1440
1460
1480
1500
1520
1540
1560
1580
1600
1620
0
434
494
506
1023
1291.1
1599
1619
1919.5
1622
1630.5
1637.2
All fluid sampling tubing, geophone cables and
gauge cables run to surface. From surface to
1200 mkb filled with inhibited fluid (water). All
instrumentation strapped to 2 3
Operate 8" tubing string.
at low DP
State #1 State #2
Cement Top at 1200 mkb
Inject Return
Return
Fluid Sampling Port #1 at 1301mkb. Port
located within Upper Lea Park zones where
porosity is ~ 7%
Pressure/temp. gauges at 1302 mkb.
Pressure/temp. gauges at 1611 mkb.
In the middle of the Cardium Zone
Fluid Sampling Port #2 at 1622 mkb.
Port located within Upper/Middle
Cardium SST
Geology(Top) for 1002/7-11-48-9W5 (approx. 35 m from Obs Well)
8 Geophone String. Bottom phone at
1640 mkb and phone spacing is 20 m.
Sample
Sample
Inject
Poppet with 0.022" hole Very light spring
(~1psi crack pressure)

56. Complex Flow Modeling

57. 1100
1120
1140
1160
1180
1200
1220
1240
1260
1280
1300
1320
1340
1360
1380
1400
1420
1440
1460
1480
1500
1520
1540
1560
1580
1600
1620
Observation Well
Pressures
P2
100/7-11 well (the OBS Well)
I1
P1
102/7-11 well (the newly drilled production well)
6500
6000
5500
5000
WH (kPa)
http://pennwest.civil.ualberta.ca/index.htm
26000
24000
22000
20000
18000
16000
4500
P-1302mkb
P-1611mkb
Inj10-11 P (kPa)
Jan/1 Mar/1 May/1 Jul/1 Sep/1 Nov/1
Pressure, kPa
Wellhead (Surface) Pressure, kPa
Date/Time
RESERV.

58. Research Programs
 Underground Coal Gasification
 Integration of Measurement, Monitoring and Verification
into Risk Management Frameworks
 Well Integrity – From Operations to Abandonment to
Post-Closure
 Numerical Modelling of CO2 Storage to Support Long-
Term Liability Transfer of CO2 Geological Storage Sites
 Continuum/Discontinuum Modelling for Assessment of
Geomechanical Monitoring Technologies
 Constitutive Properties to Support Storage Site
Performance Predictions and Monitoring Program
Design
 Monitoring Technologies for In Situ Stress
Measurements

59. Efficient and robust implementation of
reservoir-geomechanics simulation models
5479000
5480000
5481000
5482000
5483000
588000 589000 590000 591000 592000
North (m)
East (m)
Pressure Contour in Phase 1A
at May 2001
6
8
10
12
14
16
18
20
22
Phase 1A and Nine Patterns (Geomechanical Model)
East
586000 587000 588000 589000 590000 591000 592000 593000
North
5476000
5478000
5480000
5482000
5484000
5486000
Well 101141400614W200
Well 101161400614W200
Well 101141300614W200
Well 191121800613W200
Well 101161800613W200
Well 101082500614W200
Well 101162400614W200
Well 101161300614W200
Well 101081300614W200
Well 101161200614W200
Well 191101200614W200
Pressure History of Phase 1A
Jul-57
Jan-58
Jul-58
Jan-59
Jul-59
Jan-60
Jul-60
Jan-61
Jul-61
Jan-62
Jul-62
Jan-63
Jul-63
Jan-64
Jul-64
Jan-65
Jul-65
Jan-66
Jul-66
Jan-67
Jul-67
Jan-68
Jul-68
Jan-69
Jul-69
Jan-70
Jul-70
Jan-71
Jul-71
Jan-72
Jul-72
Jan-73
Jul-73
Jan-74
Jul-74
Jan-75
Jul-75
Jan-76
Jul-76
Jan-77
Jul-77
Jan-78
Jul-78
Jan-79
Jul-79
Jan-80
Jul-80
Jan-81
Jul-81
Jan-82
Jul-82
Jan-83
Jul-83
Jan-84
Jul-84
Jan-85
Jul-85
Jan-86
Jul-86
Jan-87
Jul-87
Jan-88
Jul-88
Jan-89
Jul-89
Jan-90
Jul-90
Jan-91
Jul-91
Jan-92
Jul-92
Jan-93
Jul-93
Jan-94
Jul-94
Jan-95
Jul-95
Jan-96
Jul-96
Jan-97
Jul-97
Jan-98
Jul-98
Jan-99
Jul-99
Jan-00
Oct-00
Nov-00
Dec-00
Jan-01
Feb-01
Mar-01
Apr-01
May-01
Pressure (MPa)
Design
5
0
10
15
20
25
30
Minimum
Maximum
Average
In-situ Pressure
Waterflood (1964) Vertical Infill (1986) Horizontal Drilling (1991) CO2 Injection (Fall 2000)
Field
Operations
Reservoir
Surveillance
• Time lapse Sensors
• Tilt-meters
• Micro-seismic Monitoring
• Pressure/Temperature-meters
Reservoir
Optimization
Geo-mechanical
Simulation
• Analytical/Numerical Modeling
• Full Field Simulation
• History matching
How much physics
is enough to capture
essential features
of behavior?

60. Research Programs
 Underground Coal Gasification
 Integration of Measurement, Monitoring and Verification
into Risk Management Frameworks
 Well Integrity – From Operations to Abandonment to
Post-Closure
 Numerical Modelling of CO2 Storage to Support Long-
Term Liability Transfer of CO2 Geological Storage Sites
 Continuum/Discontinuum Modelling for Assessment of
Geomechanical Monitoring Technologies
 Constitutive Properties to Support Storage Site
Performance Predictions and Monitoring Program
Design
 Monitoring Technologies for In Situ Stress
Measurements

61. Multiple scale treatment of geomechanical
attributes for reservoir simulation
Fracture
Representation
Intact Rock
Representation
Testing
Methodology
Validation
PFC Bonded
Particle Model
Sliding Joint
Model
 Nature is too complex, simplification
needed
 GRT is a “ single unit” for design and
rock modelling purposes
 1 GRT = 1 set of mechanical
properties
 GRT selected from logs, tests,
judgment
 Working on geostatistical
fundamentals on establishing GRT’s
GRT 1
GRT 2
GRT 3
GRT 4
GRT 5
GRT 6
GRT 7
GRT 8
Log data Core data

62. Reservoir Continuum/Discontinuum
Workflow
SRM
FLAC3D
RES SIM
DFN
Stress Path
OUT
Stress Path
Volumetric Strain
Pressure
Temperature
Gas Volume
Pressure
Temperature
Gas Volume
Matrix Porosity
Fracture Porosity
Permeability
Fracture Porosity
Permeability
Microseismicity
IN
OUT DDFN
Mechanical Properties
IN
IN
IN
OUT
OUT
Deformation/Stress
Results
Fluid Flow
DDFN
Mechanical Properties

63. Constitutive Properties to Support Storage
Site Performance Predictions and
Monitoring Program Design
 Research will be conducted using experimental environments
where multiphase fluid systems both upstream and downstream of
the specimens permit flow experiments under realistic stress,
deformation and temperature conditions.
 A full suite of experiments will be conducted on sandstones,
carbonates and shales to understand how both absolute and
effective permeability (to both gaseous/supercritical CO2 and
impure CO2 streams) vary as a function of stress, strain,
temperature, and injection and production history.
 A key aspect to efficient reservoir characterization and monitoring
of CO2 injection is the knowledge of the scaling relationships
between fine scale/point measurements and larger
scale/volumetric measurements. The experience and knowledge
gained during the characterization of the reservoir will also be
essential to the success of the monitoring phase.