This paper shows an experience of simulation model history matching of the field which is located in Western Siberia (Russia) and operated by PJSC “Gazpromneft”.

Main formation of the field is represented by naturally fractured reservoir M1 where the majority of oil reserves are contained within low-permeable carbonate matrix blocks and fluid flow mainly occurs due to the presence of highly conductive interconnected fractures network.

Production from M1 formation started in the latter half of 2015 and currently continues with 10 production wells. Almost all producers are subjected to the very fast water cut rise up to 80–90% during relatively short period of time. On the basis of field data analysis and taking into account that the waterflooding has not been implemented yet on the field it has been concluded that intensive water cut rise occurs as a result of water coning.

In order to history match water breakthrough time and water cut rise intensity the wettability change from water-wet to oil-wet has been modelled. It led to the decrease of water interchange between fractures and matrix blocks due to the mechanisms of capillary imbibition and gravity drainage and, as a result, provided faster advancement of water cones into producers.


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