Monitoring primary depletion reservoirs using amplitudes and time shifts from high-repeat seismic surveys

Tura, Ali; Barker, Timothy; Cattermole, Paul; Collins, C.D.M.; Davis, J. Matthew; Hatchell, Paul; Koster, Klaas; Schutjens, Peter; Wills, P.

doi:10.1190/1.2149620

Cited by 41 publications

(32 citation statements)

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“…1988, Dussealt et al 1993, Bruno and Bilak 1994, Castillo et al 1997, Massonnet et al 1997, Fielding et al 1998, Mossop and Segall 1999, Vasco et al 2000a, Stancliffe and van der Kooij 2001, Schmidt and Burgmann 2003, Vasco and Ferretti 2005 or by timelapse seismic monitoring (Guilbot and Smith 2002, Landro and Stammeijer 2004, Tura et al 2005, Hall 2006, Roste et al 2006, Rickett et al 2007, Staples et al 2007 to constrain volume and fluid pressure changes within a reservoir. Our analysis assumes that a set of deformation measurements have been gathered.…”

Section: Estimating Volume and Pressure Changes Within The Reservoirmentioning

confidence: 99%

“…These studies utilized geodetic data, such as leveling measurements, in order to quantify surface deformation related to fluid production or injection. Currently, time-lapse seismic surveys are providing additional deformation measurements, distributed throughout the overburden (Guilbot and Smith 2002, Landro and Stammeijer 2004, Tura et al 2005, Hatchell and Bourne 2005, Barkved and Kristiansen 2005, Hall 2006, Roste et al 2006, Rickett et al 2007, Staples et al 2007). Recently, the observed deformation has been used to better understand fluid flow and the heterogeneity of flow properties within the reservoir (Vasco et al 2000a, Vasco et al 2001, Du et al 2005, Vasco and Ferretti 2005, Hodgson et al 2007, Vasco et al 2008.…”

Section: Introductionmentioning

confidence: 99%

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Reservoir monitoring and characterization using satellite geodetic data: Interferometric synthetic aperture radar observations from the Krechba field, Algeria

2008

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Deformation in the material overlying an active reservoir is used to monitor pressure change at depth. A sequence of pressure field estimates, eleven in all, allow us to construct a measure of diffusive travel time throughout the reservoir. The dense distribution of travel time values means that we can construct an exactly linear inverse problem for reservoir flow properties. Application to Interferometric Synthetic Aperture Radar (In-SAR) data gathered over a CO 2 injection in Algeria reveals pressure propagation along two northwest trending corridors. An inversion of the travel times indicates the existence of two northwest-trending high permeability zones. The high permeability features trend in the same direction as the regional fault and fracture zones. Model parameter resolution estimates indicate that the features are well resolved.

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Section: Estimating Volume and Pressure Changes Within The Reservoirmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Reservoir monitoring and characterization using satellite geodetic data: Interferometric synthetic aperture radar observations from the Krechba field, Algeria

2008

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“…InSAR observations may be used to image fluid-induced deformation over regions tens to hundreds of square kilometers in extent (Fielding et al 1998, Galloway et al 1998, Amelung et al 1999, Hoffmann et al 2001, Schmidt and Burgmann 2003, Colesanti et al 2003, Vasco and Ferretti 2005. Second, recent developments in the processing of time-lapse seismic data allow for estimates of deformation in the overburden and within the reservoir (Guilbot and Smith 2002, Landro and Stammeijer 2004, Tura et al 2005, Hatchell and Bourne 2005, Barkved and Kristiansen 2005, Hall 2006, Roste et al 2006, Staples et al 2007, Hawkins et al 2007). Such estimates offer high resolution, three-dimensional sampling of deformation over a producing reservoir.…”

Section: Introductionmentioning

confidence: 99%

Estimating permeability from quasi-static deformation: Temporal variations and arrival-time inversion

2008

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Transient pressure variations within a reservoir can be treated as a propagating front and analyzed using an asymptotic formulation. From this perspective one can define a pressure 'arrival time' and formulate solutions along trajectories, in the manner of ray theory. We combine this methodology and a technique for mapping overburden deformation into reservoir volume change as a means to estimate reservoir flow properties, such as permeability. Given the entire 'travel time' or phase field, obtained from the deformation data, we can construct the trajectories directly, there-by linearizing the inverse problem. A numerical study indicates that, using this approach, we can infer large-scale variations in flow properties. In an application to Interferometric Synthetic Aperture (InSAR) observations associated with a CO 2 injection at the Krechba field, Algeria, we image pressure propagation to the northwest. An inversion for flow properties indicates a linear trend of high permeability.

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“…Landrø and Stammeijer (2004), Røste et al (2006), and Ghaderi and Landrø (2009) present different methods to estimate reservoir thickness variations from velocity changes, using differences in seismic amplitudes and time-shifts. Tura et al (2005) use a closed-loop workflow in which the static and dynamic reservoir model properties are updated with the objective of matching production data, time-lapse seismic amplitudes, and time-shifts.…”

Section: Introductionmentioning

confidence: 99%

Estimation of changes in saturation and pressure from 4D seismic AVO and time-shift analysis

et al. 2011

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A reliable estimate of reservoir pressure and fluid saturation changes from time-lapse seismic data is difficult to obtain. Existing methods generally suffer from leakage between the estimated parameters. We propose a new method using different combinations of time-lapse seismic attributes based on four equations: two expressing changes in prestack AVO attributes (zero-offset and gradient reflectivities), and two expressing poststack time-shifts of compressional and shear waves as functions of production-induced changes in fluid properties. The effect of using different approximations of these equations was tested on a realistic, synthetic reservoir, where seismic data have been simulated during the 30-year lifetime of a water-flooded oil reservoir. Results found the importance of the porosity in the inversion with a clear attenuation of the porosity imprint on the final estimates in case the porosity field or the vertically averaged porosity field is known a priori. The use of a first-order approximation of the gradient reflectivity equation leads to severely biased estimates of changes in saturation and leakage between the two different parameters. Both the bias and the leakage can be reduced, if not eliminated, by including higher-order terms in the description of the gradient, or by replacing the gradient equation with P-and/or S-wave time-shift data. The final estimates are relatively robust to random noise, as they present fairly high accuracy in the presence of white noise with a standard deviation of 15%. The introduction of systematic noise decreases the inversion accuracy more severely.

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Monitoring primary depletion reservoirs using amplitudes and time shifts from high-repeat seismic surveys

Cited by 41 publications

References 0 publications

Reservoir monitoring and characterization using satellite geodetic data: Interferometric synthetic aperture radar observations from the Krechba field, Algeria

Reservoir monitoring and characterization using satellite geodetic data: Interferometric synthetic aperture radar observations from the Krechba field, Algeria

Estimating permeability from quasi-static deformation: Temporal variations and arrival-time inversion

Estimation of changes in saturation and pressure from 4D seismic AVO and time-shift analysis

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