1. CO2 Storage
Dr AK (Tony) Booer,
Schlumberger Carbon Services, Abingdon, UK
11 Jan, 2012
UKCCSC Winter School @ Cambridge, UK
www.slb.com/carbonservices

2. Schlumberger Public
© 2012 Schlumberger. All rights reserved.
An asterisk is used throughout this presentation to denote a mark of
Schlumberger. Other company, product, and service names are the
properties of their respective owners.

3. CO2 Storage
● Finding Geological Storage
● Accessing the Storage Formation
● Monitoring Injection & Storage
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● A Real Example
● Summary

4. Schlumberger Public
Geological Storage

5. Finding the right Storage Site
What do we need?
Other:
Injectivity: • Environment
The ease with • Infrastructure
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which the CO2 • Regulation
can be injected • Public opinion
• Finance
Capacity: Containment:
The amount of The ability to
CO2 that can store CO2
be safely safely and
stored permanently
…the best risk reduction approach is to choose the right site in the first place

6. Finding the right Storage Site
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7. Modeling & Measurement to reduce Uncertainty
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8. Storage Options
Stored in geological formations:
● Depleted oil or gas fields
Depth:
● Deep saline formations
1,500 – 3,000m
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5,000 – 10,000ft
TWO KEY POINTS:
Storage sites are NOT huge caverns…
…but „solid rocks‟ like a sponge.
Secondary
CO2 is NOT a gas, at depth, seals
but like a dense liquid.
Primary
seals
„Enhanced Oil Recovery‟ is NOT the same as storage. Storage
reservoir

9. Storage mechanisms & containment
Storage sites evolve over time...
● Structural & stratigraphic trapping
● Residual – in pore space
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● Solubility – in water
● Mineralisation – “turned to stone”
Oil & gas fields demonstrate
storage times of millions of years.
Natural accumulations of CO2 have
been safely stored for millions of years.
from IPCC, 2005

10. North Sea offers storage options for UK & Europe
North Sea has an abundance of
depleted oil & gas reservoirs and
deep saline formations.
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● Should we go for many small
stores or a few large ones ?
● Which ones should they be ?
● Studies for pipeline networks
(need to know where to go!)
Source for Figure:
Pöyry Energy Consulting Study on CCS costs,
commissioned by UK Government

11. Depleted Oil and Gas reservoirs or saline formations ?
Depleted Oil or Gas reservoir: Saline Formation:
Location known Location known roughly
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Capacity known, limited Capacity less known, larger
Capacity
Injectivity known Injectivity unknown
Low pressure Normal pressure Injectivity
Containment works for oil/gas Containment not proven
Caprock properties unknown Caprock properties unknown
Lots of wells, integrity unknown Few wells Containment

12. CO2 Storage already done on an industrial scale
In Salah each
Sahara desert, ~1 M-tonne
Algeria of CO2 per
year
Weyburn
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Canada, at end Sleipner
of 200km Norwegian
pipeline North Sea
Remote
regions have
fewer public
awareness
issues
CO2 can be Carbon
transported taxes
long distances work!
by pipeline
Courtesy of IEA Weyburn CO2 Storage and Monitoring Project , BP, Sonatrach, and Statoil 12

13. CO2 Enhanced Oil Recovery versus Storage
Enhanced Oil Recovery Storage
● CO2 rate depends on ● CO2 rate determined by source
production strategy (eg. power station)
● CO2 recycled ● CO2 in long-term storage
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● Legislation under ● Legislation under new CO2 regime
petroleum industry (high public awareness)
● Operational Monitoring only ● Long-term monitoring
● Revenue from hydrocarbon ● Revenue from price of carbon
(eventually – current projects
government subsidized)
Significant experience in CO2 pipelines and
injection wells gained from US EOR
activities in the last 30+ years.

14. Accessing the
Storage
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Formation
Image courtesy of MGSC, all rights reserved.

15. CarbonWorkFlow
CO2 Injection
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Development
Closure
Appraisal /
Characterization
Post closure
Performance Management
& Risk Control
Pre Selection Post liability transfer
Pre-injection Injection Post-injection
CarbonWorkFlow* process for long-term CO2 storage enabling assessment and
management of risk in every phase of a project.
*Mark of Schlumberger

16. Wellbore Integrity – the challenge
Not just a „hole in the ground‟
―a complex hydro-mechanical system designed to fulfil many requirements:
• Shape: really strange (2km long, 20cm wide → 10,000 : 1 aspect ratio)
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● Connects the surface to storage formation
● Holds the borehole open
● Long-lasting
● Unaffected by CO2
● Materials – steel, cement, elastomers, fluids
● Barriers for fluid flow
● Economical – cost effective
● Repairable
● Geologically compatible
● Environmentally acceptable
● Retirement strategy – „plug and abandon‟
6 inch line, 1pt = 432 : 1

17. Regulation – a well also has to be legal
US Environmental Protection Agency, Class VI well guidelines
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Major goal is to
protect
underground
sources of
drinking water
(USDWs)

18. CO2 well integrity – it‟s not just the injection well
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USDW
wells
CO2 Pressure
injection relief
well well
Monitoring Abandoned
well well

19. Interfaces – some critical points
1. wellhead
2. USDW boundary
3. borehole – cement
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4. cement – casing
5. casing – annulus
6. annulus – tubing
7. tubing – CO2
8. packer – casing & tubing
9. caprock – storage formation
10. well – storage (perforations)
From US Environmental Protection Agency, Class VI well guidelines

20. Possible leakage paths across a single cemented annulus
What can go wrong?
● no isolating material where required Contaminated
Injection
tubing
― (wrong volumes)
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cement
― losses during placement Casing
● incomplete isolating material coverage Vertical
― “mud channel” fracture
● improper bond with formation Pipe
― “mud removal” debonding
● improper bond with tubular Formation Mud
debonding
― “micro-annulus” channels
● isolating material not performing
― contamination during placement
― mechanical failure during well life

21. Mitigation of leakage through wells
A full well design based on risk assessment
● Position of well components
● Definition of overlaps
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● Where to use each cement system /
completion materials
● Providing secondary barriers
as much as possible
● Robust construction practices required

22. Monitoring Injection & Storage
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23. CO2 Monitoring – 3 objectives
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USDW
wells #3: Monitor the environment
#2: Watch possible leakage paths
CO2
injection
#1: Watch stored CO2 Pressure
relief
well well
Monitoring Abandoned
well well
Detection & Quantification

24. A Practical Example:
Illinois Basin – Decatur Project
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25. Acknowledgements
The Midwest Geological Sequestration Consortium (MGSC)
is funded by the U.S. Department of Energy through
the National Energy Technology Laboratory (NETL)
via the Regional Carbon Sequestration Partnership Program
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(contract number DE-FC26-05NT42588)
and by a cost share agreement with
the Illinois Department of Commerce and Economic Opportunity,
Office of Coal Development through the Illinois Clean Coal Institute.
The Midwest Geological Sequestration Consortium
is a collaboration led by the geological surveys of
Illinois, Indiana, and Kentucky

26. DOE‟s Carbon Sequestration Program Goals
Develop Technology Options by 2020 That...
Deliver technologies & best practices that provide
Carbon Capture and Safe Storage (CCSS) with:
● 90% carbon dioxide (CO2)
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capture at source
● 99% storage permanence
● < 10% increase in
Cost of Energy (COE)
― Pre-combustion capture (IGCC)
● < 35% increase in COE
― Post-combustion capture
― Oxy-combustion

27. Illinois Basin – Decatur Project
Phase III Awarded December 2007
Major Project Elements:
● Underground Injection Control (UIC) permitting: January 2008 – November 2011
― application, hearing, minor modification, major modification, completion reports…
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● Injection well drilled: February 14 - May 4, 2009
● Geophone well drilled: November 2009
● Baseline 3D seismic survey completed: January 2010
● Compression / dehydration / pipeline facility
― design, procurement, construction, testing, February 2009-October 2011
● Monitoring well drilled, cased: Sept-Nov 2010
● Monitoring well completion: May-June 2011
● Completion Report to Illinois Environmental Protection Agency (EPA): August 2011
● Permission to Inject: November 2011
● Initiate injection: November 16, 2011
● Operating injection at a rate of 1000 tonnes/day
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28. Illinois Basin – Decatur Project Scope
A collaboration of
● Illinois State Geological Survey
● MGSC
● Archer Daniels Midland Company (ADM)
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― CO2 source + site location
● Schlumberger Carbon Services
― Storage and monitoring
● Trimeric
― Compression & dehydration
● and other subcontractors
to inject 1 million metric tons
of anthropogenic CO2
at a depth of ~7,000 ft (~2,000 m)
to test geological carbon sequestration in
a saline formation at a site in Decatur,
Illinois
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29. MGSC
Illinois Basin –
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Decatur Project
(IBDP) Site
MGSC monitoring well
MGSC Injection and geophone wells
photo by Illinois Dept.
0.5 mile of Transportation,
8 November 2010

30. 800 m
800 m
D D
D
Illinois Basin – Decatur Project
Test Site
E (on ADM industrial site)
C
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CC
A. Dehydration / Compression
B
facility location
B. Pipeline route
C. Injection well
B
B
D. Verification/ monitoring well
E. Geophone well
A
AA
IDOT Image 19-May-2010 30

31. Surface Facilities: Dual 550 TPD Reciprocating
Compressors with Dehydration
Shell and tube heat exchangers
Cooling water Dehydration
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Supply & return unit contactor
Inlet separator
Dehydration inlet separator
Discharge separator
Motor Blower
Suction scrubber Compressor
Pipeline to wellhead Blower aftercooler 31

32. Compressor Installation
March 2010
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September 2010
December 2010
Images courtesy of MGSC, all rights reserved. 32

33. Wellhead Installed, Pipeline Constructed,
Injection Begun!
January 2010 Injection day – November 2011
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Supply end at compressors
Images courtesy of MGSC, all rights reserved.

34. Monitoring Framework
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35. Baseline 3D Geophysical Survey
Completed January 2010
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36. Surface Measurement Components
● Pipeline Pressure & Temperature
● Ambient Meteorological Data
―Wind speed & direction
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―Barometric pressure
―Relative Humidity
―Rainfall
● CO2 Mass Flow Rate
● Vented CO2 Mass Flow Rate

37. Shallow Measurements
Red: groundwater well
Yellow: soil flux rings (118)
Blue: shallow resistivity points
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Injection
well
Soil flux measurements
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38. Groundwater Monitoring Wells Installed
13 groundwater wells:
● 4 for regulatory purposes
● 9 for research purposes
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175
Calcium Magnesium Potassium
150
Concentration, mg/L
125
100
75
50
25
0
Jun-09
Nov-09
Jun-10
Jul-09
Jul-10
May-09
May-10
Jan-10
Aug-09
Aug-10
Oct-09
Dec-09
Sep-09
Feb-10
Mar-10
Apr-10
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39. Three Deep Wells – Subsurface Monitoring
Injection Well (7,230 ft) Geophone Well (3,500 ft) Monitoring Well (7,272 ft)
● Wellhead Pressure & ● Multi-level ● Wellhead/Tubing
Temperature Geophone Array Pressure
● Annulus Pressure & ― 31-levels, ● Tubing-Casing Annulus
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3-component packages
Fluid Volume ― 4D Vertical Seismic
Pressure
― Monitors integrity of Profile Surveys ● Westbay* multilevel
tubing & packer ― Cemented in place groundwater
● Fiber-optic (DTS) ― Additional passive characterization and
Temperature seismic data monitoring system
― Temperature profile ― Modular multi-packer
along tubing design
● Microseismic Geophones ― Pressures &
(PS Platform* PS3) Temperatures
― 3-levels, 4-component ― Fluid sampling ports
packages ● Many of these ― Quality Assurance (QA)
― Monitors near-wellbore Zone
measurements ● Two zones above
seismicity integrated in a caprock
● Bottomhole Pressure & real-time on-site ● One in caprock
Temperature monitoring system ● Nine in storage
formation
* Mark of Schlumberger

40. Pre-injection Background Monitoring
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Earth Tide Cycles Observed in Reservoir Pressure
• Pressure/Temperature gauge in injection well tubing @ 6,325‟ (MD)
• Fluctuations in reservoir pressure caused by gravitational influences of sun and moon

41. Pre-injection Background Monitoring
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0.7 °F/100-ft
1.6 °F/100-ft
0.6 °F/100-ft
Lithology-Influenced Geothermal Gradient
• Notable changes in thermal gradient associated with transitions in lithology
• Indicative of thermal properties of various formation types

42. Monitoring Data Flow
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Diagram from G. Picard

43. Schlumberger Public
Summary

44. CO2 Storage - Summary
● Finding Geological Storage
― Capacity, Injectivity, Containment + non-technical aspects
― Depleted reservoir, or saline formation ?
― CCS not the same as CO2 EOR
Schlumberger Public
● Accessing the Storage Formation
― A well is not just a “hole in the ground”
― Consider existing wells and new ones
― Quality of execution is essential over and above good design and materials
● Monitoring Injection & Storage
― Monitoring is critical part of storage design
― Large number of technology options – not all applicable everywhere
― Requirement to monitor for many years after injection ceases
● A Real Example
― Illinois Basin – Decatur Project
― 4 years from funding decision to injection
― In operation NOW.