As a part of the Institute's strategic focus on assisting CCS projects through knowledge sharing, three North American roadshow events will help the industry share project experiences and knowledge about CCS. Taking place in the US and Canada, the three events include: • Austin, Texas on November 8, 2011; • Calgary, Canada on 10 November, 2011; and • Washington, D.C. on 19 January, 2012. The first roadshow focused on sharing project experiences and knowledge from the projects in North America but also brought in projects from Europe (Don valley) and Australia (Callide) so that regionally diverse experiences could be shared amongst a global audience. Attendance at the event was around 30 to 35 which allowed open and frank discussions around technical, management, and regulatory issues and how these challenges can impact on a project’s advancement and decision making processes.

1. Research on Geologic CO2
Storage
Ian Duncan
Gulf Coast Carbon Center
University of Texas at Austin,
Bureau of Economic Geology

2. Acknowledgements
• Gulf Coast Carbon Center researchers: Susan Hovorka, Tip Meckel,
Jiemin Lu, JP Nicot, Katherine Romanak, Changbing Yang, David Carr,
Becky Smyth, Jong-Won Choi
• BEG Associate Director: Michael Young
• BEG Director: Scott Tinker
• Funding organizations: The Department of Energy National Energy
Technology Laboratory, Southeast Regional Carbon Sequestration
GCCC sponsors

3. Research Questions
(1) Will geologic sequestration
work?
(2) Is it safe, secure, long-term
storage?
(3) How do risks of brine
sequestration compare to CO2
EOR?

4. Why we believe that CO2
Sequestration will work
Natural gas reservoirs have kept gas
in the subsurface for tens of millions
of years
Natural CO2 reservoirs have retained
CO2

5. Why we believe that CO2
Sequestration will work
The 37 year plus record of CO2 injection
into depleted oil fields (CO2-EOR)
~ 600 million tons of CO2 transported in
pipelines in the US
~ 1,200 million tons of CO2 injected

6. Why we believe that CO2
Sequestration will work
No known significant environmental
issues
Excellent safety record

7. Why we believe that CO2
Sequestration will work
Bureau of Economic Geology’s
DOE funded Field Projects:
Frio I
Frio II
SACROC
Cranfield Phase II
Cranfield Phase III

8. GCCC Field Monitoring Programs
Cranfield
SECARB
Frio Test 1&2 Phase II&II
Texas American
Resources Denbury
SACROC
Southwest
Partnership
KinderMorgan
NM Tech NRG
Hastings
Denbury-AP-LLC

9. Funded by
Frio I Brine Pilot: DOE NETL

10. Frio Brine Pilot
Site
Injection
interval

11. Observation Well
Injection Well

12. CO2 Saturation Observed with Cross-
well Seismic Tomography vs. Modeled
Tom Daley and Christine Doughty LBNL

13. Frio 1 2004-2006
• 1600 tones CO2-A
• 1500 m deep sandstone -
saline
Funded by NETL
Lead: Hovorka/Geo-SEQ
Host: Texas American
Resources

14. Frio I Pilot Injection Project
2005 -2006
First highly instrumented brine
injection
Showed … computer simulation fate
of CO2 work well
and available technologies can
monitor CO2

15. Frio II Pilot Injection Project
2007 -2008
Second highly instrumented
brine injection
Showed … Capillary trapping of
CO2 will be a significant factor is
assuring long term secure
storage

16. Modeled evolution of phases of
CO2

17. SACROC Project
2006 -2010
First monitoring for leakage in
Permian Basin CO2 EOR site
Largest (over 80 million tons of
CO2 injected over last 37 years)
SW Carbon Sequestration
Partnership Project hosted by
Kinder Morgan (EOR Operator)

18. SACROC Access to Private Water Wells

19. SACROC Project
Showed …. No evidence of
leakage of CO2 into groundwater

20. Cranfield Injection Projects
May 6th, 2010
Washington DC

21. Denbury Onshore LLC
Sandia Technologies
LBNL
LLBL
Gulf Coast Carbon
Center Staff
Cranfield Field
USGS
ORNL
Susan Hovorka
Ramon Trevino Test Collaboration
Tip Meckel
NETL Changbing Yang
QEA
U Mississippi
Jiemin Liu
Katherine Romanak SECARB
Partnership
Rebecca Smyth
Miss State Sigrid Clift
UTPGE Masoumeh Kordi
UT DoG
University Tennessee
Stuart Coleman
Yihua Cai
Hamid Lashgari
Project
BP
Princeton
Stanford
BEG staff
Tongwei Zhang
Managed by SSEB
Jeff Paine
University Edinburgh
Bob Reedy
Robert Reed
Schlumberger Carbon Kitty Millikan
Services

22. Cranfield Phase II Project
2008 -2010
Million ton injection of CO2 into
and oil field
SECARB Sequestration
Partnership Project hosted by
Denbury (EOR Operator)

23. Cranfield Phase II (EOR) 2008-
continuing
• 1 Million tones CO2-N Key results:
• 3000 m deep fluvial sandstone • Develop above zone pressure
• SECARB Partnership (SSEB) monitoring interval (AZMI) show
Lead: Hovorka, Meckel vertical isolation
Host: Denbury Onshore LLC

24. Injection well
Tubing data
0 150
Tubing Temperature (F)
Tubing Pressure (psig)
-5 100
Satellite -10
Jul.03 Jul.04 Jul.05 Jul.06 Jul.07 Jul.08 Jul.09 Jul.10 Jul.11 Jul.12 Jul.13
Date
Jul.14 Jul.15 Jul.16 Jul.17 Jul.18 Jul.19 Jul.20 Jul.21 Jul.22 Jul.23 Jul.24 Jul.25
50
transmission
Monitoring well

26. Fluvial Depositional Environment
Stratal slicing seismic interpretation
Channel Channel
Channel
erosion erosion Channel
erosion
erosion
Average Average
H: 283 md H: 20.5 %
V: 47 md V: 20.7 %
Hongliu Zeng, BEG
Point bar Point bar

27. Dedicated observation well
Injection wells
Fault

29. Flow Modeling
Actual Injection Rates Modeled CO2 injection rate
CFU 29-10 CFU 29-12 14000 CFU 29-10 CFU 29-12
14,000
CFU 26-1 CFU 25-2 CFU 26-1 CFU 25-2
CFU 24-2 CFU 29-2 CFU 24-2 CFU 29-2
12,000 CFU 28-1 CFU 27-1 12000 CFU 28-1 CFU 27-1
CFU 29-4 CFU 48-1 CFU 29-4 CFU 48-1
CFU 29-7 CFU 29-7
10,000 10000
CO2 injection rate (Mscfd)
CO2 injection rate (Mscfd)
8,000 8000
6,000 6000
4,000 4000
2000
2,000
0
-
6/1/2008 7/21/2008 9/9/2008 10/29/2008 12/18/2008 2/6/2009 3/28/2009 5/17/2009 7/6/2009
7/1/2008 8/20/2008 10/9/2008 11/28/2008 1/17/2009 3/8/2009 4/27/2009 6/16/2009
Date
Date
Simplified CO2 injection rate
??

30. Pressure match at continuous
monitoring well
BEG Observation well
6000
5500
Pressure (psi)
5000
Measurement
4500
Calculated
Simplified CO2 injection rate
4000
2/22/2008 11/18/2010 8/14/2013 5/10/2016 2/4/2019
Date

31. Cranfield Phase II Project
2008 -2010
Showed …. Digital pressure
gauges in reservoir and at well
head are sensitive to relatively
small leaks

32. Cranfield Phase III Project
2009 -2010
First highly monitored million ton
a year injection rate into brine

33. Cranfield Phase III (stacked) 2009-
continuing
3 Million tones CO2-N
3000 m deep fluvial
sandstone (brine)
SECARB Partnership (SSEB)
Lead Hovorka, Meckel, Trevino
Host: Denbury Onshore LLC
Key results:
Time and space evolution
of saturation
ERT for CCS

34. NEW PROJECTS

35. Air-Products & Leucadia Lake Charles
Hastings 2011-2015
Planned 5 Million tones CO2- A + 8
Million tons CO2 N
2000 m deep fluvial sandstone (EOR)
Lead: Nunez, Hovorka
Host: Denbury Onshore LLC
Key results:
Test best commercial technologies for confirming
storage permanence in EOR context
Assessment of faults

36. NRG JW Parrish Plant 2012-2017
Planned 0.25 ? Million tones CO2- A
from coal-fired capture
2000 m deep
bar sandstones (EOR)
Lead: Smyth
Host: To be announced soon
Key GCCC results:
Test best commercial
technologies for confirming
storage permanence in EOR
context

37. IS CO2 SEQUESTRATION SAFE?

38. IS CO2 SEQUESTRATION SAFE?
Risks associated with CO2 sequestration
Capture plant
CO2 Pipelines
Well blowouts
Leakage of CO2 into groundwater
Leakage of CO2 into oil and gas reservoirs

39. CONCLUSIONS ABOUT RISKS
• Most risks associated with CCS
can be quantified and are similar
to other analogous industrial
activities
• Risks for well characterized,
carefully selected sites are
manageable and bounded
• Risk assessment ultimately is site
specific

40. CONCLUSIONS
CO2 sequestration is ready for
projects at true commercial scale

41. Thanks!
For more information: www.beg.utexas.edu