Improving production history matching using time‐lapse seismic data

Huang, Xuri; Meister, Laurent; Workman, Rick

doi:10.1190/1.1437866

Cited by 42 publications

(21 citation statements)

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“…There have been numerous efforts to use geophysical observations, particularly time-lapse data, to monitor fluid flow at depth. Much of this work has concentrated on seismic time-lapse, or 4D, amplitude data from oil and gas reservoirs (Barr 1973, Greaves and Fulp 1987, Nur 1989, Eastwood et al 1994, Lazaratos and Marion 1997, Huang et al 1998, Johnson et al 1998, Burkhart et al 2000, Behrens et al 2002, Arts et al 2004). Improved understanding of fluid flow in the shallow sub-surface has resulted from shallow and crosswell time-lapse electromagnetic surveys (Brewster and Annan 1994, Wilt et al 1995, Barker and Moore 1998, Binley et al 2001, Hoversten et al 2003.…”

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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Section: Introductionmentioning

confidence: 99%

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

2008

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“…Estimating reservoir properties such as permeability, based on onset times, contrasts with previous efforts that relied upon timelapse amplitude, traveltime, and waveform changes (Huang et al, 1998;Vasco et al, 2004;Vasco, 2004a;Dong and Oliver, 2005;MacBeth and Al-Maskeri, 2006;Dadashpour et al, 2008Dadashpour et al, , 2009Feng and Mannseth, 2010;Rey et al, 2012). Here, we demonstrate that onset times, extracted from seismic time-lapse reflection data recorded in a few surveys, can provide a reliable basis for reservoir characterization.…”

Section: Introductionmentioning

confidence: 72%

Reservoir characterization based upon the onset of time-lapse amplitude changes

et al. 2015

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Time-lapse geophysical monitoring has potential as a tool for reservoir characterization, that is, for determining reservoir properties such as permeability. Onset times, the calendar times at which geophysical observations begin to deviate from their initial or background values, provide a useful basis for such characterization. We found that, in contrast to time-lapse amplitude changes, onset times were not sensitive to the exact method used to related changes in fluid saturation to changes in seismic velocities. As a consequence of this, we found that an inversion for effective permeability based upon onset times was robust with respect to variations in the rock-physics model. In particular, inversions of synthetic onset times calculated using Voigt and Reuss averaging techniques, but inverted using sensitivities from Hill's averaging method, resulted in almost identical misfit reductions and similar permeability models. All solutions based on onset times recovered the large-scale, resolvable features of the reference model. Synthetic tests indicated that reliable onset times can be obtained from noisy seismic amplitudes. Testing also indicated that large-scale permeability variations can be recovered even if we used onset times from seismic surveys that were spaced as much as 300 days apart.

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“…Walker and Lane (2007) present a case study that includes time-lapse seismic data as a part of the production history matching process, and show how the use of seismic monitoring can improve reservoir prediction. Integration of disparate data has been suggested in a number of publications (Huang et al, 1998, Gosselin et al, 2001, Waggoner et al, 2002and Aanonsen et al, 2003. Though these clearly identify data integration as a means for better constraining the problem, they do not provide a clear and precise optimization methodology.…”

Section: Introductionmentioning

confidence: 98%

“…These data can be of disparate spatial distributions and temporal periodicities, such as production data and time-lapse seismic data. Huang et al (1998) formulate the simultaneous matching of production and seismic data as an optimization problem. In this scheme, the updating of model parameters (such as porosity) is not assured to honor the spatial statistics of the reservoir.…”

Section: Introductionmentioning

confidence: 99%

Robust scheme for inversion of seismic and production data for reservoir facies modeling

Echeverria

Mukerji

Santos

2009

SEG Technical Program Expanded Abstracts 2009

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This research aims at making optimal updates of geological models by jointly inverting flow and seismic data while honoring the geologic spatial continuity. Numerical models for reservoir characterization are increasing in complexity, due in part to the greater need to model the complex spatial heterogeneity and fluid flow in the subsurface. These models, once properly calibrated, can make better forecasts. This calibration process requires in essence the solving of an inverse problem. The inversion problem is formulated as minimizing the mismatch function between observations and the output of the numerical models. The optimal search is carried out by adjusting model parameters, typically one or more for each grid-point of the reservoir. The optimization problem is large-scale in nature, with a nonlinear and nonconvex objective function, that often involves time-expensive simulations. Additionally, this problem is generally ill-conditioned, because the number of degrees of freedom usually is larger than the number of observations. We present a robust and fairly efficient methodology to deal with these difficulties in the framework of oil reservoir characterization. The illconditioned character of the optimal search can be attenuated in two ways. By Principal Component Analysis (PCA) the search space can be projected to a subspace of much smaller dimension, while keeping consistency with prior spatial geological features already known for the reservoir. The number of optimal solutions can be reduced further by increasing the diversity of the data observed. We integrate two different types of data: time-lapse seismic (spatially distributed and of lower temporal periodicity) and production data (localized around wells and of high temporal periodicity). Production data provides an integrated response of the reservoir to fluid flow, while time-lapse seismic data yields a spatially distributed characterization of the changes in elastic velocities due to saturation and pressure variations. The reduction in the number of optimization variables by PCA allows the use of numerical derivatives of the cost function. Within a distributed computing framework these approximate derivatives can be calculated efficiently. We also consider derivative-free algorithms. We illustrate the methodology on a sector of the Stanford VI synthetic reservoir created for testing algorithms.

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Improving production history matching using time‐lapse seismic data

Cited by 42 publications

References 0 publications

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

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

Reservoir characterization based upon the onset of time-lapse amplitude changes

Robust scheme for inversion of seismic and production data for reservoir facies modeling

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