The determination of saturation and therefore fluid contacts can be challenging in certain low permeability reservoirs of the Yamal peninsula. The low water salinity and high shale content make contact determination with traditional petrophysical methods difficult. The low permeability also complicates contact determination using pressure gradient analysis. Downhole fluid analysis seems a logical choice, but it too is fraught with difficulties in low perm, near saturated reservoirs.
In this paper we show how to apply DFA for contact determination and how to mitigate, by interpretation and hardware configuration, the various challenges. Additionally we investigate the quality of the obtained samples with respect to their suitability for PVT studies.