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ECMOR II - 2nd European Conference on the Mathematics of Oil Recovery
- Conference date: 11 Sep 1990 - 14 Sep 1990
- Location: Arles, France
- ISBN: 978-27-1080-589-2
- Published: 11 September 1990
41 - 48 of 48 results
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Constant-Time Step Deconvolution Model for Variable-Rate Well Test Pressure Data
Authors S. Buitrago, G. Gedler and R. ManzanillaThe transient pressure well test analysis is a technique which allows the petroleum engineer to determine reservoir properties, such as permeability, porosity, the drainage volume of the reservoir, static pressure and, in general, to characterize or describe the reservoir-well system in order to indicate damage or stimulation of well, fracturing or not of well, the existence of faults or flow barriers, the approximate shape of the drainage area of the reservoir or the change of the reservoir lithological properties.
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Inverse Modeling for Compressible Flow. Application to Gas Reservoirs
Authors B. Bréfort and V. PelcéClassical methods to determine permeability distribution in a gas reservoir are sometimes inadequate: for a gas field, only core measurements are available and scale problems always appear when applying these values to the whole reservoir. An inverse modeling procedure is proposed to determine automatically the permeability field for a dry-gas reservoir. This method consists in the minimization of the difference between a historical record of real pressures and pressures computed from discretized equations of monophasic gas flow in porous medium. A Lagrangian method combined with geostatistical information is used. Two applications are presented: a history matching of a gas field giving a permeability distribution then used for prediction and a transient draw-down test on a gas well which gives an estimate of the local permeability in the surrounding matrix.
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Computer Geological Simulation in Oil Recovery
More LessAt the Siberian Scientific-Research Institute for the Oil Industry we have developed some methods of solving geological problems. They are realized in the form of a computer system GEOPAK-2. The system can solve three classes of problems providing construction of a producing formation geological model according to the type of a filtration model used: a detailed geological correlation of well profiles; an estimation of the object geological structure complexity parameters; geometrization of pools and differentiated calculation of reserves.The first of them is ba sic for solving the others.The re sults of solving the second one are used in oil recovery estima tion procedures based on one—di mensional statistical models of filtration.The solution of the third-class problems is necessary when using two- and three-dimensional determined models of filtration.
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A New Formulation for Generalised Compositional Simulation
Authors R. E. Mott and C. L. FarmerAn important recent trend in reservoir simulation has been the development of multiple application simulators which can model both black oil and compositional processes within a single program. A number of different mathematical formulations have been proposed for solving the fluid flow equations in these simulators. With an IMPES solution scheme there are two basic approaches; Newton-Raphson methods, such as that of Young and Stephenson (1983), and the volume balance method of Watts (1986). Various fully implicit schemes have also been described. Although these methods all solve the same underlying equations, the relationship between them is not easily understood.
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P3D Modeling of Vertical Hydraulic Fracture Growth
More LessRecent short cut design procedures for hydraulic fracturing treatment are based on two dimensional geometric description: either a penny shape or constant height is supposed. Unless the minimal horizontal stress is constant along the vertical direction or a high confining stress acts in the overburden and underburden these assumptions cannot be justified.
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Irregular Averaging of Filtration Transfer Processes in Heterogeneous Media
More LessThe modification of the asymptotic method of averaging operators with rapid ly oscillating coefficients (Sanchez-Palencia, 1980, Bakhvalov et al., 1984) is suggested for the media with heavy heterogeneity (great differences in permeability of separate areas). Several new models of the filtration processes generalizing a known phenomenological simulator (Barenblatt et al., 1960) are constructed with the aid of this method. The composite has been selected as a physical model, the components of which are a connected high-conductive system and periodically scattered isolated compact blocks. The system period l is muchless than macroscale L, so ε=1/L<<1.
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History Matching Problems of Filtration Theory. Complex Adaptative Geological Models of Fields
Authors B. Palatnik, I. Zakirov and G. AgaevTo choose improved oil or gas field development its necessary to create algorithm providing the possibility to calculate a field development performance during all the period of production for the different controlled influences on the bed. The simulation reliability and therefore the validity of the accepted project decisions depends on the degree of the adequacy of the mathematical models used to real physical processes as well as on the degree of the truthfulness of the initial geological-field information used at the simulation. It is the important peculiarity of the large oil and gas fields that they have common hydrodynamical connection between processes which take place in an aquifer, in a bed, in wells and fluid gathering, compressing, cleaning and treating and field pipeline transferring systems. Therefore to carry out long-term forecast of field development performance it is necessary to create the complex adaptive mathematical model which unites both reservoir and ground technological equipment (GTE) models.
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Multilevel Methods in Porous Media Flow
Authors R. Teigland and G. E. FladmarkThe purpose of this paper is to describe the development and application of a cell-centered multilevel method applied to multiphase flow in porous media. The model that we consider is two-phase, 2-D compressible flow in a porous media. In section 2 we set up the coupled set of non linear partial differential equations to be solved and discretize them using cell-centered differencing. A fully implicit scheme with water saturation and oil pressure as unknowns is used in the solution of the system.
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