This paper presents an integrated approach to validate reservoir oil volumetries and determine their properties versus pressure used in field development planning and monitoring. This approach allows reconciliation of reservoir oil properties used both in reserves estimation and field development planning and monitoring.

The paper reviews an engineering procedure of generating an adequate multicomponent reservoir oil model based on laboratory analysis of representative reservoir oil samples and their recombination using equation of state. The procedure does not require recourse to regression analysis which is routinely used in Eclipse, VIP and other simulators.

With specific reference to hydrocarbon systems of the West Siberian fields, we review the influence of the actual onsite separation conditions and official standard concerning stock-tank oil vapor pressure on values of such volumetric parameter as formation volume factor, stock-tank oil density, solution gas-oil ratio.

Keywords:
PVT measurement, oil density, Upstream Oil & Gas, stage separation, stock-tank oil density, fraction, Artificial Intelligence, Reserve Estimation, thermodynamic model, Reservoir Oil property
Subjects:
Fluid Characterization, Phase behavior and PVT measurements
Copyright 2008, Society of Petroleum Engineers
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