in salah co2 jip: status and overview - iea greenhouse … june 3 in sal… · ·...
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Classification: Internal Status: DraftClassification: Internal Status: Draft
Kevin Dodds
on behalf of Alan Mathieson, Rob Bissell BPPhil Ringrose StatoilHydroDon Vasco, Ernie Majer LBNLJoe Morris LLNLEric Davis, Glenn McColpin Pinnacle Technologies Clare Bond MVEPeter Armitage Univ of Liverpool
In Salah CO2 JIP: Status and Overview5th IEA Monitoring Meeting, Tokyo, Japan June 2-3 2009
2
Outline
•Geological and Structural Context
•Plume development modelling - Permedia
•Key Risks Risk Evaluation URS Risqueet al
•INSAR Deformation and Inversion Pinnacle Tech, LBNL
•Geomechanical / Geochemical Modelling and Experimental Summary
–LLNL, Univ of Liverpool,
•Monitoring Update
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Krechba Key Risk Locations
KB5
44
The In Salah CO2 storage site at Krechba
Cretaceoussequence(900m)
Carboniferousmudstones(950m)
Definition and modelling of reservoir storage and
migrationReservoir (20-25m thick)
Definition and modelling of potential
cap-rock pathways
Gas Chemistrymonitoring
Fluid displacement monitoring (4D seismic)
Rock strain monitoring(Tilt, microseismic)
Productionmonitoring(Tracers)
CO2 injection(3 wells)
Gas production(5 wells)
Gas from other fields
Amine C02 removalSatellite
monitoring(InSAR)
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Conceptual Structural Geological Model for Krechba
Structural style schematic
Carboniferous reservoir (C10)• Broad folds influenced by
underlying strike-slip faults
Devonian sequence:• Deep seated faults reactivating
earlier extensional faults in dominantly strike-slip mode with some reverse faulting
Conceptual model for Krechba reservoir:• West limb of reservoir east-west faults probably
associated with fracturing
• East limb has some subtle faults and a steeper dip segment related to underlying fault activity
• Fracture density controlled by folding and faults
• Open fracture direction controlled by stress field
• Fracture density also controlled by lithology
N
Deep-seated faults propagating upwards
Minor faultsExpected
fracture zones
C10.1C10.2C20.1C20.2
Schematic of strata-bound fractures
Clare Bond MVE
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Technical questions for Research• How does subsurface CO2 injection affect rock properties (a) at the reservoir
level (b) in the overburden (c) surface deformation?
• How much is CO2 injection controlled by faults or fractures (or both)?
• Have we induced fractures in the reservoir (a) mechanically (b) thermally?
• What flow parameters control dispersion and channelling of the CO2 plume: (a) rock property heterogeneity (b) fracture distribution (c) rock mechanical response (d) fluid properties & PVT?
• How can the current monitoring dataset/package be best used to calibrate our models and ultimately long-term storage verification?
• What additional data should/could we be measuring?
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Faulting
• Subtle faults best detected on low-angle illumination of time surface (pre-reprocessed dataset)
• Reservoir model faults digitized using Gocad
Subtle seismic features that are not
seismic artefacts
Modelled Faults:• No dip information• Based on seismic
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Fault 12
KB-502
Analysis shows that:• Fault 12 could be open under the
current-day stress field.• Main fracture set is also closely
aligned with current-day field• Other fault and fracture sets more
likely closed/cemented/old
Faults and Fractures
σ1
σ1
Fault 12All digitised fault data
East
South
West
North
σ1
σ1
KB502 fractures
σ1
σ1
Main
fractures
Second
Fracture
set
Clare Bond MVE
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Permedia Study- mPath Andrew Cavanagh CO2 Toolkit
• Invasion percolation approach (capillary limit)• Preliminary result from high resolution mesh (400M cells)• Next stage will compare black-oil simulation with IP approach
Topographic control Fault control Fault & fracture control
1010
Well observations:• CO2 from injector KB-502
detected at appraisal well KB-5 after 2 years injection(Distance 1.3km)
Satellite Data:• Deformation ellipse detected
around injector• Larger area than the
breakthrough zone
Reservoir history match (Eclipse):• 4D permeability corridor
(suspected fault?)• Fracture flow also important
The KB-502 Story(First Break, 27, January 2009)
Injection wellKB-502
GWC
Observation well KB-5
Zone of surfacedeformation
Conductivefractureorientation
History-matched CO2 plume
Possible CO2 plume extension
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Risk assessment aims• General aims to assess:
– the risk of leakage (containment risk) from the intended reservoir– the capacity of the site to store the intended mass of CO2 at the planned rates (effectiveness risk)
• Specific aims to provide outputs that help BP to:– understand and communicate containment risk
• understand and communicate effectiveness risk• identify knowledge gaps• develop strategies to reduce risk
• URS Risque process used, – Externally acceptable, benchmarked on a number of projects
• Gorgon, Otway, Weyburn, Zerogen– Independent review process using external managed process
• URS and CO2CRC representatives– Rigorously defined base case, and probabilistic scales
• Further plans– Risk workshop highlighting different processes as communication to European regulatory people,
DNV, Shell, Risque.– In Salah planning to benchmark risk processes
• RISQUE Process• CCP Certification Process UT and LBNL• CO2 PENS LANL• DNV
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Risk Assessment Process
Establish the context
Identify risks
Analyse risks
Likelihood Consequences
Estimate level of risk
Evaluate risks against targets
Strategy to treat risks
The specific aims were to provide outputs that help BP understand and communicate containment risk and effectiveness risk, and to identify knowledge gaps and develop strategies to reduce risk.
In light of updated monitoring data, review characterisation and re evaluate risks
Risk = Likelihood x consequences
(rate volume)Estimated rate of CO2 seepage (t/an)Log normal distribution
High estimate: CL 95% 60Best estimate: CL 50% 30
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KB-502 Injection OverviewKB-502 Injection Overview
• CO2 injections began in April 2005
– Slow start-up of ~200 MMscf per month through Aug 2007
• CO2 Injections ramp up to a maximum of 907 MMscf in December 2007
– Steady decline in injection volume through August 2006 (468 MMscf)
• Two additional periods of injection ramp-up and decline after September 2007
– Steep decline in injection volume after May 2007
• CO2 identified in adjacent well KB-5 in early August 2007
• CO2 injections were shut-in August 2007
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Track 65: 11-29-2003 to 01-22-2005Track 65: 11-29-2003 to 01-22-2005
Note the temporal decorrelation due to sand movement. This feature is not filtered out within these SVD optimized interferograms to preserve near-well
deformation magnitudes.
Pinnacle Technologies March 26,2009
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Track 65: 11-29-2003 to 09-24-2005Track 65: 11-29-2003 to 09-24-2005
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Track 65: 11-29-2003 to 03-18-2006Track 65: 11-29-2003 to 03-18-2006
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Track 65: 11-29-2003 to 03-22-2008Track 65: 11-29-2003 to 03-22-2008
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Track 65: 11-29-2003 to 05-31-2008Track 65: 11-29-2003 to 05-31-2008
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Track 65: 11-29-2003 to 05-31-2008Track 65: 11-29-2003 to 05-31-2008
NE-SW lineation near KB-14 (seen in
JGI images) not observed in these
datasets
Believed to be a atmospheric artifact carried through from
the 7-31-2004 master image NW-SE lineation
(fault?)
• Delineates western margin of deformation at KB-501
• Trend passes through a “deformation trough” at KB-502Zoom in on KB-501 and KB-503
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Modelling Tasks for 2009
Jan 09 Jul 09Apr 09 Dec 09Oct 09
Model convergence
E300 simulations
MPath simulations
Flow Simulation
Stars coupled modelCO2/CH4
mixing
Coupled modelling workshop with R&D partners
Long-term CO2 storage
Input to R&D Partners (LLNL, LBNL, Pinnacle, CO2ReMoVe)
R&D Model insights
Improved parameterization
Validation and peer review
Monitor/Model coupling
Microseismic, Timelapse seismic, Satellite/surface, Chemical monitoring, Production monitoring, Hydrogeology
Model updates
Structural restoration and fracture prediction (MVE)
Characterisation
Update datasets (JV/JIP)
Fracture modelling (History Match DFM of kb502/kb5 area)
Generate model grids
Rock mechanical modelling and properties
Laboratory analyses (U of L., LLNL, JIP)
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Monitoring Overview
Year 2009 involves a major effort in monitoring activities at Krechba ($12M)• 3D/4D Seismic – Northern field area (improved imaging and time-lapse)• Microseismic test well – KB601 drilled to 500m with geophone string)• Tiltmeters/DGPS – in the KB501 area; 64 tiltmeter and 3 DGPS stations• Satellite Imagery – whole field; monthly acquisition programme• Observation wells to monitor potable aquifer – two to be drilled in 2009• Surface gas flux, Lineament Analysis, microbiology – being done by
CO2ReMoVe (BGS, BRGM, Uiv. Rome)• Wellhead Annulus Monitoring – continual (from 2006) gas composition and
tracer analysis (IFP and IFE)• Data acquisition from development/water wells – KB-15, KB-16 and KB-17
– Cuttings analysis, headspace gas– Electric logs, behind casing sonic (MSIP)
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