Time-lapse pressure–saturation discrimination for CO2 storage at the Snøhvit field

Grude, Sissel; Landrø, Martin; Osdal, B.

doi:10.1016/j.ijggc.2013.09.014

Cited by 57 publications

(49 citation statements)

References 10 publications

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“…Landrø et al (2003) exploited AVO to estimate pressure and saturation changes from marine multicomponent time-lapse seismic data. Grude et al (2013) 168 F. Huang et al…”

Section: Evaluation Of Co 2 Saturation and Pressure Based Anomaliesmentioning

confidence: 99%

Quantitative evaluation of thin-layer thickness and CO₂mass utilizing seismic complex decomposition at the Ketzin CO₂storage site, Germany

Huang

Juhlin

Han³

et al. 2016

Geophys. J. Int.

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S U M M A R YDetermining thin layer thickness is very important for reservoir characterization and CO 2 quantification. Given its high time-frequency resolution and robustness, the complex spectral decomposition method was applied on time-lapse 3-D seismic data from the Ketzin pilot site for CO 2 storage to evaluate the frequency-dependent characteristics of thin layers at the injection level. Higher temporal resolution and more stratigraphic details are seen in the all-frequency and monochromatic reflectivity amplitude sections obtained by complex spectral decomposition compared to the stacked sections. The mapped geologic discontinuities within the reservoir are consistent with the preferred orientation of CO 2 propagation. Tuning frequency mapping shows the thicknesses of the reservoir sandstone and gaseous CO 2 is consistent with the measured thickness of the sandstone unit from well logging. An attempt to discriminate between pressure effects and CO 2 saturation using the extracted tuning frequency indicates that CO 2 saturation is the main contributor to the amplitude anomaly at the Ketzin site. On the basis of determined thickness of gaseous CO 2 in the reservoir, quantitative analysis of the amount of CO 2 was performed and shows a discrepancy between the injected and calculated CO 2 mass. This may be explained by several uncertainties, like structural reservoir heterogeneity, a limited understanding of the complex subsurface conditions, error of determined tuning frequency, the presence of ambient noise and ongoing CO 2 dissolution.

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“…Landrø et al (2003) exploited AVO to estimate pressure and saturation changes from marine multicomponent time-lapse seismic data. Grude et al (2013) 168 F. Huang et al…”

Section: Evaluation Of Co 2 Saturation and Pressure Based Anomaliesmentioning

confidence: 99%

Quantitative evaluation of thin-layer thickness and CO₂mass utilizing seismic complex decomposition at the Ketzin CO₂storage site, Germany

Huang

Juhlin

Han³

et al. 2016

Geophys. J. Int.

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“…is influenced by both pore pressure and saturation changes. Two methods have been applied to separate these effects (Grude et al, 2013;White et al, 2014). Both methods focus on the lowermost Tubåen 1 sandstone unit where 80% of the injected CO 2 migrated.…”

Section: Co 2 Layer Thickness and Saturation From Time-lapse Seismic mentioning

confidence: 99%

“…Capillary pressure limits vertical CO 2 migration between the Tubåen 1 and 2 sandstone units. Grude et al (2013) inverted for injection related pore pressure and saturation changes from near and far stack time-lapse seismic. The inversion algorithm was introduced by Landrø (2001) and uses rock physics to relate the seismic parameters to pressure and saturation.…”

Section: Co 2 Layer Thickness and Saturation From Time-lapse Seismic mentioning

confidence: 99%

“…Patchy (Voigt, 1887) and uniform (Reuss, 1929) fluid mixing models represent the upper and lower bounds for the fluid distribution. (Grude et al, 2013) compared the CO 2 saturation obtained from the upper and lower bounds with the CO 2 saturation derived using an intermediate CO 2 distribution, represented by the Brie equation with an exponent e = 3 in the inversion. The Brie's equation of fluid moduli reads K f = (K Brine − K CO 2 )S 3 Brine + K CO 2 (Brie et al, 1995).…”

Section: Co 2 Layer Thickness and Saturation From Time-lapse Seismic mentioning

confidence: 99%

“…(Hansen et al, 2013). Time-lapse amplitude versus offset (AVO) inversion (Grude et al, 2013) and spectral decomposition (White et al, 2014) were used to separate the pressure and fluid effects on the timelapse seismic data. This study develops a better understanding of CO 2 saturation and layer thickness in the Tubåen Fm.…”

Section: Introductionmentioning

confidence: 99%

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CO2 saturation and thickness predictions in the Tubåen Fm., Snøhvit field, from analytical solution and time-lapse seismic data

Grude¹,

Landrø²,

White

et al. 2014

International Journal of Greenhouse Gas Control

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a b s t r a c t CO 2 migration in a saline aquifer is governed by viscous, capillary and gravitational fluid forces at an early stage of injection, where the dominant flow regime is site specific and controls the fluid migration in the pore space. This study combines the CO 2 saturation inverted from time-lapse seismic methods with an analytical expression to define the CO 2 flow regime, saturation distribution and layer thickness in the Tubåen Fm. following CO 2 injection. Quantitative estimates of the CO 2 saturation from time-lapse seismic amplitude versus offset (AVO) and spectral decomposition are compared to a viscous dominated analytical expression of CO 2 injection into a saline aquifer. The spatial extent of the CO 2 plume obtained from time-lapse spectral decomposition and inverted from time-lapse AVO analysis display good agreement with the analytical expression. The CO 2 is limited to an area close to the injection well, with an elongated shape in the channel direction. Comparison between the time-lapse seismic and analytical expression shows that the fluid flow is dominated by viscous forces. CO 2 saturation within the plume is constant and close to the residual brine saturation. The influence of gravity is ignorable on the reservoir CO 2 flow. CO 2 fills the entire sandstone unit up to approximately 50 m away from the injection before the CO 2 layer thickness is reduced to a thin wedge that propagates below the overlying shale unit. Reduction in CO 2 saturation away from the injection well is a reduction in effective CO 2 saturation relative to the thickness of the horizon. The maximum radius of the CO 2 layer from the analytic expression is 750 m, of which 400 m is above the time-lapse noise level. Time-lapse seismic analysis reveals the CO 2 layer radius is 405 m in the direction of the local fluvial channel and 273 m in the perpendicular direction.

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Seismic Reservoir Modeling

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Time-lapse pressure–saturation discrimination for CO2 storage at the Snøhvit field

Cited by 57 publications

References 10 publications

Quantitative evaluation of thin-layer thickness and CO₂mass utilizing seismic complex decomposition at the Ketzin CO₂storage site, Germany

Quantitative evaluation of thin-layer thickness and CO₂mass utilizing seismic complex decomposition at the Ketzin CO₂storage site, Germany

CO2 saturation and thickness predictions in the Tubåen Fm., Snøhvit field, from analytical solution and time-lapse seismic data

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Time-lapse pressure–saturation discrimination for CO2 storage at the Snøhvit field

Cited by 57 publications

References 10 publications

Quantitative evaluation of thin-layer thickness and CO2mass utilizing seismic complex decomposition at the Ketzin CO2storage site, Germany

Quantitative evaluation of thin-layer thickness and CO2mass utilizing seismic complex decomposition at the Ketzin CO2storage site, Germany

CO2 saturation and thickness predictions in the Tubåen Fm., Snøhvit field, from analytical solution and time-lapse seismic data

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Quantitative evaluation of thin-layer thickness and CO₂mass utilizing seismic complex decomposition at the Ketzin CO₂storage site, Germany

Quantitative evaluation of thin-layer thickness and CO₂mass utilizing seismic complex decomposition at the Ketzin CO₂storage site, Germany