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Understanding the fundamental uncertainties related to CO 2 geologic storage

Understanding the fundamental uncertainties related to CO 2 geologic storage . A case study in Nugget Suite west of Hogback thrust Guang Yang, MS Candidate. Introduction. Basic workflow in reservoir modeling and simulation

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Understanding the fundamental uncertainties related to CO 2 geologic storage

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  1. Understanding the fundamental uncertainties related to CO2geologic storage A case study in Nugget Suite west of Hogback thrust Guang Yang, MS Candidate

  2. Introduction • Basic workflow in reservoir modeling and simulation structural modelinglithofaciesmodelingpetrophysicalmodelingupscaling(if applicable)flow simulation • Uncertainties associated with these steps • Possible pollution to shallow freshwater • Identify the most influential factor(s) controlling CO2 storage, leakage and potential hazards

  3. Research approach • Data Collection Collect as much data as we can get (including analog data) • Geological modeling Using hierarchical modeling and most reasonable geostatistical scheme • Reservoir Simulation Freshwater and saline water interface change? • Sensitivity Analysis Experimental Design

  4. Data Collection • Geophysical & geological data • Water chemistry data • No seismic data • Engineering data Core measurements Well-log data • Data sources: NETL Rocky Mountain Basins Produced Water Database Wyoming EOR Reservoir Database Wyoming Oil & Gas Conservation Commission(Well logs)

  5. Study site Nugget Suite After Lamerson, 1983

  6. Geological analog • Data in nearby production fields • Data in other eolian sandstone formation literature reference Our Model Domain Kupfersberger and Deutsch, 1999

  7. Uncertainties • Heterogeneity of the reservoir at various scales • Fracture (enhanced vertical permeability) • Boundary condition (sealing fault or non-sealing fault, recharge rate) • Facies distribution (probability maps & vertical proportion curve3d-cube?) • Porosity and permeability distribution trend & depth trend • Relative permeability hysteresis

  8. Preliminary results *Preliminary facies interpretation of the model with the location of injection wells *Limited well data to generate 3d facies distribution probability cube

  9. Preliminary results • Porosity depth trend which would be incorporated into porosity modeling

  10. Preliminary results • Kv/Kh, Khmax/Kh90deg which would be incorporated into permeability modeling Based on core measurements at nearby sites

  11. Flow Simulation • Eclipse Gaswater • Eclipse CO2STORE(need to extract a part of the model) (Salinity tracking, no water-rock interaction) • 267,500 grid cells • Relative permeability curves (Bennion and Bachu, 2005, 2006) • Zero capillary pressure • Injection started from Jan. 2010, stopped in 2060. Monitored till 3410 • Initial Condition & Boundary Condition(Aquifer Modeling) Hydrostatic, constant head for i+,j+,j- boundaries.i-,k+,k-closed. • Bottom Wellbore Pressure constraint (Zhou et al., 2008) 1.8*hydrostatic pressure

  12. Preliminary Simulation Result

  13. Preliminary Simulation Result 1 Gas saturation change in injector3 1 Gas saturation change in injector 4

  14. Ongoing work • Investigate the possible 3 zones of nugget sandstone as indicated by data From the W29-12 well in Anschutz Ranch East Field,Lindquist,1986

  15. Ongoing work • Possible porosity distribution based on data from other sites (Can we infer the porosity trend based on that?)

  16. Ongoing work Using alternative facies & petrophysical property simulation methods: *Combining SIS and annealing method (Christopher J. Murray, AAPG book,1994) *Gaussian collocated cosimulation algorithm (Alberto, AAPG book, 1994, Y. Z. Ma SPE, 2008)

  17. Ongoing work • Investigate how to generate a saline water and freshwater interface or salinity distribution in Petrel

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