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Abstract

Summary

In previous studies of the authors presented at the ECMOR-XIV and ECMOR-XV, an adjoint-based geostatistically-consistent approach was proposed for automated history matching of reservoir models. In the approach, reservoir property and facies distributions in a 3D models are consistently modified in the efficient iterative history matching procedure, with control parameters being anisotropic variogram parameters for the facies distribution and for reservoir properties distributions within each facie, as well as parameters of poroperm petrophysical correlations and values at pilot points. Derivatives of the objective function are obtained with adjoint method taking into account geostatistical relations between reservoir properties and variogram parameters. A concept of continuous "facies" and a weighting method for reservoir property calculations were also developed.

In this study we present the results of validation and further development of the geostatistically-consistent procedures for history matching.

In the first part of the study, we show and analyze the results of multivariant synthetic validation of the approach with simultaneous identification of anisotropic variogram parameters and reservoir properties at pilot points.

Then we describe the application of the continuous-facies approach to modeling of lithofacies and reservoir properties distributions for a real massive terrigenous gas reservoir in Western Siberia. We show that it proved successful in reflecting highly-heterogeneous distribution of reservoir properties with lens-like inclusions while preserving the overall geological consistency and continuous nature of sedimentation in the 3D model.

It is interesting to note that previous 3D dynamic flow model for field development planning was manually history matched through simulation of reservoir bodies' discontinuity. In other words, variogram ranges were artificially lowered for achieving desired level of reservoir disconnectivity. From production data analysis it is clear that gas-water contact advanced locally in vicinities of producing wells instead of an overall global contact elevation in accordance with global pressure distribution. Almost 80% of initial gas in place has been already produced, and pressure declined to almost 20% of its initial value. At this stage of development one could expect global displacement of gas by water, but reservoir heterogeneity played an important role forming hard-to-recover gas reserves at distant reservoir zones. All these peculiarities were successfully taken into account within the new 3D model built for a geostatistically-consistent history matching to production data. The results of this study would be presented in a conference paper and presentation.

© EAGE Publications BV
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/content/papers/10.3997/2214-4609.201802142
2018-09-03
2024-04-25

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Geostatistically-Consistent History Matching Of Lithofacies And Reservoir Properties Applied To Synthetic and Real-Field Cases
Conference Proceedings 2018, 1 (2018); https://doi.org/10.3997/2214-4609.201802142
/content/papers/10.3997/2214-4609.201802142
/content/papers/10.3997/2214-4609.201802142
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