A methodology for building and history matching of an oil deposit model is presented, the parameters of which are consistent with the actual well production and initial geological and geophysical data. Petrophysical, geologic and hydrodynamic models are considered as parts of a unified model, or as submodels, when synchronous adjustment of the parameters of submodels is carried out using laws describing the whole system. Productive layers of the modeling object are terrigenous deposits with clay and carbonate cements, characterized by significant lithological vertical heterogeneity. Multiparameter dependencies connecting the porosity and permeability of rocks with the content of clay and carbonate cements are used for building a petrophysical submodel. Clay and carbonate rock properties are introduced through the normalized values of gamma and neutron logs. The principle of invariance of the differential filtration equations is applied to find the connate water saturation of rocks. Timur-Coats equation is used as an invariant. Spectral modeling of geophysical fields is applied to propagate the geologicl features of heterogeneous reservoir, which are further interpreted by petrophysical dependencies. Core data are used for the initial determination of parameters of petrophysical dependencies, their correction is carried out during the history matching of the hydrodynamic submodel. Closing relationships of the filtration equations system provide synchronous adjustment of the parameters of the petrophysical, geologic and hydrodynamic submodels and automatic history matching. Testing of the proposed methodology was carried out at one of the oil deposits in Western Siberia, which is characterized by interbedding of sandstones and siltstones with clay and carbonate interlayers. Good convergence of calculated and actual deposit development indicators with a minimum number of iterations is achieved.
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