key technologies and solutions in providing reliable and ... · key technologies and solutions in...
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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
Distance
dependant
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 Storage
Site Selection Site Characterization (SCP) Field Design
/ Site PreparationSite Construction Injection
Per
form
ance
& R
isk
M
anag
emen
t Sys
tem
(P
RM
ST
M)
Com
mun
icat
ion
and
Pub
lic A
ccep
tanc
e
SE
VE
RIT
Y
-11L
-21S
-41 C
-31M
-51M C
- 22 L
- 41S
- 62 M
- 82C
- 1 02 M C
-33L
-63 S
-93M
- 1 23 C
- 1 53M C
-44L
- 55 L
-84S
-1 24 M
-1 64 C
-2 04 MC
- 1 05 S
- 1 55M
- 2 05C
- 2 55M C
- 1L ig 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 l ti- Ca ta s tro p h i c
321
Po
ssible
Un
likely
Imp
rob
able
5
Prob
able
4
Like
ly
L IK EL IH O O D
W h i te a rr o w i n d ic a te s d e c re a s in g r is k
P RE V E N TIO N
M I TIG A TIO N
C o n tr o lM e a su r e s
R E D
BL U E
Y E LL O W
G RE E N
IN T O LE R A B LE : D o no t t ak e th is ris k
UN D E S IR A B L E : D em ons t ra te A L A R P be fo re p roc eed ing
A C C E P T A B LE : P roce ed c a re fu lly , w ith c on t inuous im prov em ent
NE G LIG IB LE : S a fe to p r oce ed
-1 6 to -10
- 9 to -5
- 4 to -2
-1
B LAC K N O N -O P ER AB L E : E va c ua t e th e zo n e a n d o r a re a/ co u nt ry-2 5 to -20
Pre-Operation
Phase
~ 10-50 years
~ 2-5 year
Operation
Phase
~50-100+years
Post-Injection
PhaseSite 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 Treatment
PreventionRemediation
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 & Properties
Geophysics
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 – E300
Calibration on monitoring measurements(History match)
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Capacity – MeasurementsStructure
�High-Resolution Seismic, VSP’s and Sonic
Properties
�Borehole imagers �Formation Evaluation
Gamma Ray (GR)0 (GAPI) 200
Micronormal (HMNO)20 0Microinverse (HMIN)
20 0
Caliper6 (IN) 16
SP-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
Modeling to Surface
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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 logsDrilling reports
Well geometry
Cement degradationCasing corrosionCO2 migrationLimit 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€
F
Financial
Envir.3rd-PPeople
C
SAFETY
6 : Catastr.
5 : Critical
4 : Major
3 : Serious
2 : Marginal
1 : Minor
…B
Asset
A
Reliability &availability.
Stakes
Level
>20 M€
<20 M€
<5 M€
<1 M€
<0,2 M€
F
Financial
Envir.3rd-PPeople
C
SAFETY
6 : Catastr.
5 : Critical
4 : Major
3 : Serious
2 : Marginal
1 : Minor
…B
Asset
A
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 leakage
Type of leakage to expect X
=
An Integrated Solution to:
• Leakage and Degradation Modeling• Leakage scenarios• Risk criticality estimation
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Prevention Evaluation� Sonic Scanner� Isolation Scanner
� Good drilling practices
� Cement job planning
Geo
Ste
erin
gS
tone
fish
Materials
2 days 6 weeks1 week
� Metallurgy� CO2-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 well
Frio 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 Integrity
Microseismicity events are micro cracks occurring in the formation due to pressure increase
Listening to these cracks is a powerful monitoring technique
� Detection, Location in 3D and Classification of Microseismicity Events
� Control of Pumping Rate to Avoid Fracturing the Cap Rock
� Detection of Fault Reactivation
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Schlumberger involved CO2 Storage Projects
IdF
CCP2
MGSC
Mountaineer
PCORMRSCP
Frio
Weyburn II
Gorgon
OtwayCO2CRC
Callide
COACH
InSalahHassi Touareg
Karniow
KetzinSleipner
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)