Key technologies and solutions in providing reliable and efficient CO2 geological storage services

Transcription

1 Key technologies and solutions in providing reliable and efficient CO2 geological storage services Geneva, 27 th of November, 2007 Presenter Hanspeter Rohner Vice President, Europe & Australia

2 2 CO2 Capture and Geological Storage 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

3 The CCS Cost (or Value!) Chain 3 Capture Transport Storage Monitoring $20-50/t CO 2 $1-10/t CO 2 $2-10/t CO 2 $ /t CO 2 IPCC Estimations: NGCC $44/t CO 2 PC $29/t CO 2 IGCC $20/t CO 2 Sensitive to Energy prices IPCC:(500km) Ships $10/t CO 2 Hydro:(250km) Pipeline: 230M$ University of Newcastle Pipeline 570M$/y Distance dependant IPCC: Aquifer $0.5-8/t CO 2 Pöyry: Aquifer $2/t CO 2 Gas or oil field $9.5/t CO 2 Sensitive to Reservoir quality IPCC: $ /t CO 2 Benson et Al 2006 $0.16/t CO 2 Remediation not included

4 -25 to -20 BLACK NON-OPERABLE: Evacuate the zone and or area/country -16 to -10 RED IN TO LE RA B LE : D o n ot take th is risk -9 to -5 YELLOW UNDESIRABLE: Demonstrate ALARP before proceeding -4 to -2 GREEN ACCEPTABLE: Proceed carefully, with continuous im provement -1 BLUE N E GLIG IBL E: S afe to proceed MITIGATION Control Measures 1 5 PREVENTION Light Serious Major Catastrophic L -2 1S -3 1M -4 1C -5 1MC LIKELIHOOD L 3L 4L -4 1S -6 2M -8 2C -10 2MC -6 3S -9 3M -12 3C -15 3MC Multi-Catastrophic -5 W hite arrow indicates decreasing risk -8 4S -12 4M -16 4C -20 4MC -5 5L -10 5S -15 5M -20 5C -25 5MC An Integrated Solution to CO2 Storage 4 Pre-Operation Phase Site Selection Site Characterization (SCP) Field Design ~ 2-5 year Operation Phase ~ years Post-Injection Phase Site Construction Site Retirement Programme (SRP) / Site Preparation Injection Environmental Monitoring (M&V) Operation Verification Performance & Risk Management System (PRMS) Communication and Public Acceptance ~ years SEVERITY Improbable Likely Possible Unlikely Probable

5 Performance & Risk Management System 5 Regulatory Framework Performance & Risk Assessment Capacity Injectivity Containment Measurement for Characterization Functions / Stakes Cost Environment Heath & Security Image Modeling Risk Treatment Prevention Remediation Monitoring Measurements Construction Technologies & Interventions

6 Initial Assessment Site Characterization 6 Data Collection & QC Sequence, Stratigraphy & Property Model Dynamic Modeling (flow, geomechanics, geochemistry) Geophysics / Geology Petrophysics / Mineralogy Geomechanics Fluid Properties Well Integrity Injectivity Capacity Containment From CO2CRC Latrobe Valley Study

7 Building a Static Model Structure & Properties Geophysics Flow / Transport Seismic Well Correlation Fault Modeling 7 Geology Geomechanics PETREL Petrophysics Mineralogy Petrophysical Modeling Zonation and Layering Model needs to include overburden Facies Modeling

8 CO2 Injection Dynamic Modeling 8 Upscaling ECLIPSE E300 Calibration on monitoring measurements (History match) Thermodynamics Geochemistry CO2 Concentration in Water 3D Full Compositional Flow Simulator Thermal Modeling Geomechanics Simulator Monitoring Data

9 Capacity Measurements Structure High-Resolution Seismic, VSP s and Sonic 9 Properties Borehole imagers Mineralogy Formation Evaluation :20 RSOZ 0 DSOZ M Micronormal (HMNO) 20 0 Pad Microinverse (HMIN) Gamma Ray (GR) (GAPI) Caliper (IN) SP (MV) 0 RT 1 (OHMM)100 0 HALS Deep 1 (OHMM)100 Resistivity (HLLD) 0 HALS Shallow 1 (OHMM)10 Resistivity (HLLS) 00 MCFL Rxo (RX18) 1 (OHMM)100 0 High Resolution 1.95 (G/C Density (RHOZ) 3 )2.95 Neutron Porosity 45 (PU) -15 (NPOR) Crossplot Porosity 45 (PU) -15 (PXND) PEF 0 10

10 Injectivity 10 Permeability Core Logs Formation testers Well tests Injection induced near-wellbore effects Dry-out Salt precipitation Carbonate dissolution The Reservoir Dry-out Simulation near the Wellbore is crucial for Injectivity Prediction Optimization Injection well design, placement and number Hydraulic fracturing Dry-out Zone CO 2 Reactive Transport Fluid Phases Equilibration Gas Saturation

11 Injectivity - Measurements 11 Permeability from Wireline Logging Permeability from Well Testing

12 Containment 12 Caprock & Overburden Hydrostratigraphy Composition Mechanical properties Flow properties Faults Transmissibility Mechanical Properties Wells Completions state Isolation issues Degradation mechanisms Modeling to Surface (from Damen et al, 2003) Importance of reservoir geomechanics and evaluation of wells (from Latrobe Valley study, CO2CRC, 2005)

13 Containment Measurements for Geomechanics 13 Along the wellbore trajectory: Elastic Strength Earth Stress & Pore Pressure 10 0 Young s Modulus Poisson s Ratio Friction Angle 20 UCS 400 Stress Direction S h 0 Stress MPa 200 W N E fault? PR Ε UCS Φ P p S h S H S V Regional Trend

14 Containment Integrity of Wells (1) 14 Data & input Characterisation Cement logs Drilling reports Well geometry Conclusions Can we re-use existing wells? More data needed? Probability of leakage Type of leakage to expect Static model minor weak middle high critical Sensitivity analysis Risk mitigation options Cost / Benefits ranking Cement degradation Casing corrosion CO2 migration Limit conditions An Integrated Solution to: Leakage and Degradation Modeling Leakage scenarios Risk criticality estimation 5 B = Detection Evolution Dynamic model = Stakes Level 1 : Minor 2 : Marginal 3 : Serious 4 : Major 5 : Critical 6 : Catastr. F Financial <0,2 M <1 M <5 M <20 M >20 M K (t) CO2 (t) H2O (t) Leak amount & probability A Reliability & availability. X B Asset People C SAFETY 3rd-P Consequence grid & transfert fonction Envir.

15 Containment Integrity of Wells (2) 15 GeoSteering Stonefish Prevention Good drilling practices Optimal Well Placement Materials Metallurgy CO2-Resistant cement + 2 days 1 week 6 weeks + Evaluation Sonic Scanner Isolation Scanner Cement job planning WellCLEAN

16 Monitoring and Verification during CO2 Injection 16 Geophysical techniques: Logging: Sampling: Permanent sensors: Seismic, VSP s, EM techniques, microseismicity Saturation (Resistivity, Sigma), Well integrity (Casing corrosion, cement bond) Pressure, Fluid properties, CO2 concentration Pressure, Temperature

17 CO 2 Displacement from Seismic - Sleipner Baseline Survey 17 CO 2 Injection Start: Sept D Seismic Survey 1994 Interpretation of flow patterns (CO2 displacement and trapping) Verification of cap rock integrity Courtesy of Statoil CO 2 Injector Well CO 2 below shale layers

18 Well Logging for CO2 Breakthrough Frio CO 2 saturation measurement along a monitoring well Frio brine experiment in Texas: Changes of Σ from time lapse logs 18 Injection start: Oct 4 th, Injection duration: 10 days (*) Sakurai et al., SPWLA 46 th June th

19 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 19 Detection, Location in 3D and Classification of Microseismicity Events Control of Pumping Rate to Avoid Fracturing the Cap Rock Detection of Fault Reactivation

20 Schlumberger involved CO2 Storage Projects 20 Weyburn II PCOR CCP2 MGSC MRSCP Frio Mountaineer Sleipner IdF InSalah Ketzin Karniow Hassi Touareg COACH MOVECBM PETRONAS Gorgon Callide Otway CO2CRC

21 Conclusions 21 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) The Technology is ready! But continuous investment in Engineering and Learning While Doing

22 22 Thank You!