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• W1986659900 abstract "Abstract This paper presents an integrated approach to validate reservoir oil volumetrics 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, stocktank oil density, solution gas-oil ratio. Introduction The experience gained by the authors shows that reconciliation of reservoir oil properties used both in reserves estimation and field development planning and monitoring is very important. An inextricable connection is to be maintained between validation of volumetrics and hydrocarbon system properties when estimating (reestimating) reserves, preparing an oil-recovery feasibility study and a field development plan. An integrated use of production, laboratory and scientifically grounded computational procedures constitute the basis of an efficient approach to improve the quality of crude-oil volumetrics validation and field development planning. Reserves estimation and development planning requires valid hydrocarbon fluid properties averaged by reservoir. One of the crucial requirements is a uniform availability of representative samples for each of the reservoirs (in terms of area and volume). This will allow an insight into the compositional analysis and physical and chemical properties of the reservoir hydrocarbon systems. Typically two procedures are used to collect representative samples for reservoir oil analysis 1,5:Downhole sampling;Separator Sampling. Collection of representative samples should meet the following fundamental requirements: Downhole sampling At least three samples are required for reservoir oil PVT analysis. The pressure at the hydrocarbon system sampling point should exceed bubble point pressure, i.e. the analyzed fluid should be in single phase. Recombined separator samples In case downhole sampling is not feasible the analysis is performed using a recombined sample made of separator samples of oil and gas. Recombination is based on the measured GOR value. If a two-phase gas-liquid system is obtained once the recombined sample is reduced to reservoir pressure and temperature, the hydrocarbon liquid phase (under-gas-cap zone) and hydrocarbon gas phase (gas cap) are analyzed individually. Estimation of oil and solution-gas reserves are based on the oil formation volume factor under initial reservoir pressure and temperature, solution GOR and stock-tank oil density derived from the onsite stage separation analysis. Validation of volumetrics should be based on the actual conditions exiting at the booster pumping station and the requirements specified in the GOST R 51858–2002 on stock oil vapor pressure 2,3. However, the authors experience shows that laboratory analyses are often performed at universal temperature of 20°C and separation stage pressures of 0.8 ?P?, 0.25 ?P?, 0.101325 ?P?." @default.
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• W1986659900 date "2008-10-28" @default.
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• W1986659900 title "New method of systemic substantiation of reservoir crude properties in calculation of reserves and field development designs" @default.
• W1986659900 doi "https://doi.org/10.2118/117391-ms" @default.
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