www.slb.com/carbonservices
CO2 Storage
Dr AK (Tony) Booer,
Schlumberger Carbon Services, Abingdon, UK
11 Jan, 2012 UKCCSC Winter School @ Cambridge, UK
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© 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.
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CO2 Storage
● Finding Geological Storage
● Accessing the Storage Formation
● Monitoring Injection & Storage
● A Real Example
● Summary
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Geological Storage
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What do we need?
Finding the right Storage Site
…the best risk reduction approach is to choose the right site in the first place
Capacity:
The amount of
CO2 that can
be safely
stored
Injectivity:
The ease with
which the CO2
can be injected
Containment:
The ability to
store CO2
safely and
permanently
Other:
• Environment
• Infrastructure
• Regulation
• Public opinion
• Finance
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Finding the right Storage Site
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Modeling & Measurement to reduce Uncertainty
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Storage Options
Stored in geological formations:
● Depleted oil or gas fields
● Deep saline formations
TWO KEY POINTS:
Storage sites are NOT huge caverns…
…but „solid rocks‟ like a sponge.
CO2 is NOT a gas, at depth,
but like a dense liquid.
Storage
reservoir
Primary
seals
Secondary
seals
Depth:
1,500 – 3,000m
5,000 – 10,000ft
„Enhanced Oil Recovery‟ is NOT the same as storage.
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Storage sites evolve over time...
● Structural & stratigraphic trapping
● Residual – in pore space
● Solubility – in water
● Mineralisation – “turned to stone”
Oil & gas fields demonstrate storage times of millions of years.
Storage mechanisms & containment
from IPCC, 2005
Natural accumulations of CO2 have
been safely stored for millions of years.
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Source for Figure:
Pöyry Energy Consulting Study on CCS costs,
commissioned by UK Government
North Sea offers storage options for UK & Europe
North Sea has an abundance of
depleted oil & gas reservoirs and
deep saline formations.
● 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!)
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Containment
Injectivity
Capacity
Depleted Oil and Gas reservoirs or saline formations ?
Depleted Oil or Gas reservoir:
Location known
Capacity known, limited
Injectivity known
Low pressure
Containment works for oil/gas
Caprock properties unknown
Lots of wells, integrity unknown
Saline Formation:
Location known roughly
Capacity less known, larger
Injectivity unknown
Normal pressure
Containment not proven
Caprock properties unknown
Few wells
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CO2 Storage already done on an industrial scale
12 Courtesy of IEA Weyburn CO2 Storage and Monitoring Project , BP, Sonatrach, and Statoil
Weyburn
Canada, at end
of 200km
pipeline
Sleipner
Norwegian
North Sea
In Salah
Sahara desert,
Algeria
each
~1 M-tonne
of CO2 per
year
CO2 can be
transported
long distances
by pipeline
Carbon
taxes
work!
Remote
regions have
fewer public
awareness
issues
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CO2 Enhanced Oil Recovery versus Storage
Enhanced Oil Recovery
● CO2 rate depends on
production strategy
● CO2 recycled
● Legislation under
petroleum industry
● Operational Monitoring only
● Revenue from hydrocarbon
Storage
● CO2 rate determined by source
(eg. power station)
● CO2 in long-term storage
● Legislation under new CO2 regime
(high public awareness)
● Long-term monitoring
● 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.
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Accessing the Storage Formation
Image courtesy of MGSC, all rights reserved.
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CarbonWorkFlow
Pre Selection
Appraisal /
Characterization
Development
CO2 Injection
Closure
Post closure
Post liability transfer
Performance Management
& Risk Control
Pre-injection Injection Post-injection
*Mark of Schlumberger
CarbonWorkFlow* process for long-term CO2 storage enabling assessment and
management of risk in every phase of a project.
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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)
● 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
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Regulation – a well also has to be legal
US Environmental Protection Agency, Class VI well guidelines
Major goal is to
protect
underground
sources of
drinking water
(USDWs)
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CO2 well integrity – it‟s not just the injection well
Pressure
relief
well Abandoned
well
Monitoring
well
CO2
injection
well
USDW
wells
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1. wellhead
2. USDW boundary
3. borehole – cement
4. cement – casing
5. casing – annulus
6. annulus – tubing
7. tubing – CO2
8. packer – casing & tubing
9. caprock – storage formation
10. well – storage (perforations)
Interfaces – some critical points
From US Environmental Protection Agency, Class VI well guidelines
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Possible leakage paths across a single cemented annulus
What can go wrong?
● no isolating material where required ― (wrong volumes) ― losses during placement
● incomplete isolating material coverage ― “mud channel”
● improper bond with formation ― “mud removal”
● improper bond with tubular ― “micro-annulus”
● isolating material not performing ― contamination during placement ― mechanical failure during well life
Injection tubing
Casing
Contaminated cement
Vertical fracture
Formation debonding
Mud channels
Pipe debonding
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Mitigation of leakage through wells
A full well design based on risk assessment
● Position of well components
● Definition of overlaps
● Where to use each cement system /
completion materials
● Providing secondary barriers
as much as possible
● Robust construction practices required
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Monitoring Injection & Storage
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CO2 Monitoring – 3 objectives
Pressure
relief
well Abandoned
well
Monitoring
well
CO2
injection
well
USDW
wells
#1: Watch stored CO2
#2: Watch possible leakage paths
#3: Monitor the environment
Detection & Quantification
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A Practical Example: Illinois Basin – Decatur Project
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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
(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
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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)
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
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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…
● 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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Illinois Basin – Decatur Project Scope
A collaboration of
● Illinois State Geological Survey
● MGSC
● Archer Daniels Midland Company (ADM) ― 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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MGSC Illinois Basin – Decatur Project (IBDP) Site
MGSC Injection and geophone wells
MGSC monitoring well
0.5 mile
photo by Illinois Dept.
of Transportation,
8 November 2010
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Illinois Basin – Decatur Project Test Site (on ADM industrial site)
A. Dehydration / Compression
facility location
B. Pipeline route
C. Injection well
D. Verification/ monitoring well
E. Geophone well
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A
B
C
D
800 m
A
B
C
D
800 m
D
E
C
B
A
IDOT Image 19-May-2010
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Surface Facilities: Dual 550 TPD Reciprocating Compressors with Dehydration
Inlet separator Dehydration inlet separator
Dehydration
unit contactor
Blower
Discharge separator
Blower aftercooler
Suction scrubber
Shell and tube heat exchangers
Cooling water
Supply & return
Compressor
Motor
Pipeline to wellhead
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March 2010
September 2010
December 2010
Compressor Installation
Images courtesy of MGSC, all rights reserved.
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Wellhead Installed, Pipeline Constructed, Injection Begun!
Supply end at compressors
January 2010 Injection day – November 2011
Images courtesy of MGSC, all rights reserved.
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Monitoring Framework
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Baseline 3D Geophysical Survey Completed January 2010
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Surface Measurement Components
● Pipeline Pressure & Temperature
● Ambient Meteorological Data
―Wind speed & direction
―Barometric pressure
―Relative Humidity
―Rainfall
● CO2 Mass Flow Rate
● Vented CO2 Mass Flow Rate
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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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Groundwater Monitoring Wells Installed
13 groundwater wells:
● 4 for regulatory purposes
● 9 for research purposes
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0
25
50
75
100
125
150
175
May
-09
Jun-
09Ju
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Aug
-09
Sep
-09
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-09
Nov
-09
Dec
-09
Jan-
10Fe
b-10
Mar
-10
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-10
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-10
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-10
Con
cent
ratio
n, m
g/L
Calcium Magnesium Potassium
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Three Deep Wells – Subsurface Monitoring
Injection Well (7,230 ft)
● Wellhead Pressure & Temperature
● Annulus Pressure & Fluid Volume ― Monitors integrity of
tubing & packer
● Fiber-optic (DTS) Temperature ― Temperature profile
along tubing
● Microseismic Geophones (PS Platform* PS3) ― 3-levels, 4-component
packages ― Monitors near-wellbore
seismicity
● Bottomhole Pressure & Temperature
Geophone Well (3,500 ft)
● Multi-level Geophone Array ― 31-levels,
3-component packages ― 4D Vertical Seismic
Profile Surveys ― Cemented in place ― Additional passive
seismic data
● Many of these measurements integrated in a real-time on-site monitoring system
Monitoring Well (7,272 ft)
● Wellhead/Tubing Pressure
● Tubing-Casing Annulus Pressure
● Westbay* multilevel groundwater characterization and monitoring system ― Modular multi-packer
design ― Pressures &
Temperatures ― Fluid sampling ports ― Quality Assurance (QA)
Zone ● Two zones above
caprock ● One in caprock ● Nine in storage
formation
* Mark of Schlumberger
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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
Pre-injection Background Monitoring
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Lithology-Influenced Geothermal Gradient
• Notable changes in thermal gradient associated with transitions in lithology
• Indicative of thermal properties of various formation types
Pre-injection Background Monitoring
0.6 °F/100-ft
1.6 °F/100-ft
0.7 °F/100-ft
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Monitoring Data Flow
Diagram from G. Picard
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Summary
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CO2 Storage - Summary
● Finding Geological Storage ― Capacity, Injectivity, Containment + non-technical aspects ― Depleted reservoir, or saline formation ? ― CCS not the same as CO2 EOR
● 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.