Schlumberger Private
Key technologies and solutions in providing reliable and efficient CO2 geological storage services
Geneva, 27th of November, 2007Presenter Hanspeter RohnerVice President Schlumberger Carbon Services, Europe & Australia
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CO2 Streams• Coal and Gas Power Plants• Associated gas production• LNG process• Gas-to-Liquid process• Heavy Oil production• Coal-to-Liquid process• Hydrogen
• Refineries• Heavy industry
• Steel mills• Cement factories• Aluminum mills
Saline Aquifers
CO2 Capture and Geological Storage
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The CCS Cost (or Value!) Chain
$20 - 50/t CO2 $1 - 10/t CO2 $2 - 10/t CO2 $0.1 - 0.3/t CO2
Capture MonitoringStorageTransport
IPCC Estimations:NGCC $44/t CO2PC $29/t CO2IGCC $20/t CO2
Sensitive to Energy prices
IPCC:(500km)Ships $10/t CO2
Hydro:(250km)Pipeline: 230M$University of NewcastlePipeline 570M$/y
Distancedependant
IPCC: Aquifer$0.5 - 8/t CO2
Pöyry: Aquifer$2/t CO2Gas or oil field$9.5/t CO2
Sensitive to Reservoir quality
IPCC:$0.1 - 0.3/t CO2
Benson et Al 2006$0.16/t CO2
Remediation not included
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An Integrated Solution to CO2 StorageSite Selection Site Characterization (SCP) Field Design
/ Site PreparationSite Construction Injection
Per
form
ance
& R
isk
M
anag
emen
t Sys
tem
(PR
MS
)C
omm
unic
atio
n an
d P
ublic
Acc
epta
nce
SEVERITY
-11 L
-21 S
-41 C
-31 M
-51 M C
-22 L
-41 S
-62 M
-82 C
-1 02 M C
-33 L
-63 S
-93 M
-1 23 C
-1 53 M C
-44 L
-55 L
-84 S
-1 24 M
-1 64 C
-2 04 M C
- 1 05 S
- 1 55 M
- 2 05 C
- 2 55 M C
-1Lig h t
-2
-3
-4
-5
S e rio u s
M a jo r
C a ta s tro p h ic
M u lti-C a ta s tro p h ic
321
Possible
Unlikely
Improbable
5
Probable
4
Likely
L IK E L IH O O D
W h ite a rro w ind ic a te s d e c re a s in g ris k
P R E V E N TIO N
M IT IG AT IO N
C o n tro lM e a s u re s
R E D
B L U E
Y E L L O WG R E E N
IN T O LE R A B LE : D o n o t t ak e th is ri sk
U N D E S IR A B LE : D em on stra te A LA R P be fo re p ro cee d in g
A C C E P T A B LE : P roc eed ca re fu lly , w ith co n tin uou s im p rove m e nt
N E G LIG IB L E : S a fe to p roc eed
-16 to -1 0
-9 to -5
-4 to -2
-1
B L A C K N O N -O P E R A B LE : E v ac ua te th e z on e a nd or a rea /co un try-25 to -2 0
Pre-Operation Phase
~ 10-50 years
~ 2-5 year
Operation Phase
~50-100+years
Post-Injection Phase
Site Retirement Programme(SRP)
Monitoring (M&V)• Operation
• Verification
• Environmental
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ModelingMeasurement forCharacterization
Construction Technologies& Interventions
Monitoring Measurements
Performance & Risk Management System
Performance & Risk Assessment• Capacity• Injectivity• Containment
• Cost• Environment• Heath & Security• Image
Functions / Stakes
Risk TreatmentPreventionRemediation
RegulatoryFramework
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Initial Assessment – Site Characterization
Data Collection & QC
Sequence, Stratigraphy & Property ModelDynamic Modeling
(flow, geomechanics, geochemistry)
CapacityInjectivity
– Geophysics / Geology– Petrophysics / Mineralogy– Geomechanics– Fluid Properties– Well Integrity
From CO2CRC – Latrobe Valley Study
Containment
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Building a Static Model – Structure & PropertiesGeophysics
Geology Geomechanics
PetrophysicsMineralogy
Flow / TransportSeismic
Well Correlation
Fault Modeling
Zonation and Layering
Facies Modeling
Petrophysical Modeling
Model needs to include overburden
PETREL
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CO2 Injection Dynamic Modeling
CO2 Concentration in Water
Thermodynamics Geochemistry
Thermal Modeling
Monitoring Data
Geomechanics Simulator
Upscaling
3D Full CompositionalFlow Simulator
ECLIPSE – E300Calibration on monitoring measurements(History match)
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Capacity – MeasurementsStructure
High-Resolution Seismic, VSP’s and Sonic
PropertiesBorehole imagers Formation Evaluation
Gamma Ray (GR)0 (GAPI) 200
Micronormal (HMNO)20 0Microinverse (HMIN)20 0
Caliper6 (IN) 16SP-100 (MV) 0
Pad1:200M
RSOZDSOZ
RT
HALS Deep Resistivity (HLLD)1 (OHMM)100
0
1 (OHMM)1000
1 (OHMM) 10001 (OHMM)1000
HALS Shallow Resistivity (HLLS)MCFL Rxo (RX18)
High Resolution Density (RHOZ)1.95 (G/C3) 2.95Neutron Porosity
(NPOR)Crossplot Porosity
(PXND)PEF
45 (PU) -15
45 (PU) -15
0 10
1500
1475
Mineralogy
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Injectivity
Permeability– Core– Logs– Formation testers– Well tests
Injection induced near-wellbore effects– Dry-out– Salt precipitation – Carbonate dissolution
Optimization – Injection well design, placement and number– Hydraulic fracturing
The Reservoir Dry-out Simulation near the Wellbore is crucial for Injectivity Prediction
Dry-out Zone
CO2 Reactive Transport Fluid Phases Equilibration
0 10.5Gas Saturation
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Injectivity - Measurements
Permeability from Wireline Logging Permeability from Well Testing
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Containment
(from Damen et al, 2003)
Caprock & Overburden– Hydrostratigraphy– Composition– Mechanical properties– Flow properties
Faults– Transmissibility– Mechanical Properties
Wells– Completions state– Isolation issues– Degradation mechanisms
(from Latrobe Valley study, CO2CRC, 2005)
Importance of reservoir geomechanicsand evaluation of wells
Mode
ling t
o Sur
face
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Containment – Measurements for Geomechanics
Along the wellbore trajectory:
Strength
UCS Φ
20 400
0 70
UCS
Friction Angle
Earth Stress & Pore Pressure
Pp S h S H S V
MPa0 200Stress W N E
Stress Direction Sh
fault ?
Regional Trend
PR Ε
1Poisson’sRatio
Young’s Modulus 100
Elastic
0
10
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Containment – Integrity of Wells (1)
CharacterisationCement logs
Drilling reportsWell geometry
Cement degradationCasing corrosionCO2 migration
Limit conditions
1
23
4
56
7
8
9
1 0
1 1
1 2
1
23
4
56
7
8
9
1 0
1 1
1 2
1
23
4
56
7
8
9
1 0
1 1
1 2
1
23
4
56
7
8
9
1 0
1 1
1 2
1
23
4
56
7
8
9
1 0
1 1
1 2
1
23
4
56
7
8
9
1 0
1 1
1 2
Data & input
K(t)
1
1110
9
8
7
6
5
4
3
2
CO2(t)H2O(t)
Dynamic model
Leak amount & probability
>20 M€
<20 M€
<5 M€<1 M€
<0,2 M€
FFinancial
Envir.3rd-PPeople
CSAFETY
6 : Catastr.
5 : Critical
4 : Major3 : Serious
2 : Marginal
1 : Minor
…B
AssetA
Reliability &availability.
Stakes
Level
>20 M€
<20 M€
<5 M€<1 M€
<0,2 M€
FFinancial
Envir.3rd-PPeople
CSAFETY
6 : Catastr.
5 : Critical
4 : Major3 : Serious
2 : Marginal
1 : Minor
…B
AssetA
Reliability &availability.
Stakes
Level
Consequence grid & transfert fonction
Static model
666564636261656555453525154645444342414363534333231326252423222121615141312111654321
DetectionEvolution
Conclusions
811
13
5
00
5
10
15
20
minor weak middle high critical
B = 50
Sensitivity analysisRisk mitigation optionsCost / Benefits ranking
Can we re-use existing wells ?More data needed ?
Probability of leakageType of leakage to expect X
=
An Integrated Solution to:• Leakage and Degradation Modeling• Leakage scenarios• Risk criticality estimation
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Prevention EvaluationSonic ScannerIsolation Scanner
Good drilling practices
Cement job planning
GeoS
teer
ing
Ston
efis
h
Materials
2 days 6 weeks1 week
MetallurgyCO2-Resistant cement
+ +
Wel
lCLE
AN
Optimal Well Placement
Containment – Integrity of Wells (2)
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Monitoring and Verification during CO2 Injection
Geophysical techniques: Seismic, VSP’s, EM techniques, microseismicityLogging: Saturation (Resistivity, Sigma), Well integrity (Casing corrosion, cement bond)Sampling: Pressure, Fluid properties, CO2 concentrationPermanent sensors: Pressure, Temperature
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CO2 Displacement from Seismic - Sleipner
1994
1999 2001 2002
Baseline Survey
CO2 Injection Start: Sept 19964D Seismic Survey
CO2 Injector Well CO2 below shale layers
Interpretation of flow patterns (CO2 displacement and trapping)Verification of cap rock integrity
Courtesy of Statoil
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Well Logging for CO2 Breakthrough – Frio
(*) Sakurai et al. , SPWLA 46th – June 26-29th - 2005
CO2 saturation measurement along a monitoring wellFrio brine experiment in Texas: Changes of Σ from time lapse logs
Injection start: Oct 4th,
Injection duration: 10 days
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Cap Rock & Fault IntegrityMicroseismicity events are micro cracks occurring in the formation due to pressure increaseListening to these cracks is a powerful monitoring technique
Detection, Location in 3D and Classification of Microseismicity EventsControl of Pumping Rate to Avoid Fracturing the Cap RockDetection of Fault Reactivation
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Schlumberger involved CO2 Storage Projects
IdF
CCP2
MGSC
Mountaineer
PCORMRSCP
Frio
Weyburn II
Gorgon
OtwayCO2CRC
Callide
COACH
InSalah Hassi Touareg
KarniowKetzinSleipner
MOVECBM
PETRONAS
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Conclusions
• The Technology is ready !• But continuous investment in Engineering and Learning While Doing
• Key Technologies focus on:• Capacity-Injectivity-Containment • Long term storage integrity
• Key Technologies are• Measurement (surface and downhole in wells)• Modeling (static-dynamic-predictive)• Well Construction (drilling, cementing, completions, remediation)