A new model has been developed specifically to study very large, heterogeneous oil and gas reservoirs. By using unique approaches to the simulation of fluid properties and dual porosity/permeability systems, the model is able to accurately simUlate complex reservoir flow performance that was previously difficult or not feasible to model. Descriptions of the fluid flow characteristics of the model are included in the Appendix. Potential applications to several real field simulation problems are discussed to show the advantages of the model as compared to more traditional approaches. Additionally, several actual simulations of hypothetical reservoirs are shown and the results are compared with both standard single porosity and dual porosity black oil models currently available. The enhanced representation of the physical system compared to classical black oil models is achieved in a way which is efficient in the use of both the memory and processor resources of the computer, whilst the modular nature of the simulator, coupled with advanced programming and documentation standards, will facilitate its further development and maintenance. 305

A new model has been developed specifically to study very large, heterogeneous oil and gas reservoirs. By using unique approaches to the simulation of fluid properties and dual porosity/permeability systems, the model is able to accurately simUlate complex reservoir flow performance that was previously difficult or not feasible to model. Descriptions of the fluid flow characteristics of the model are included in the Appendix. Potential applications to several real field simulation problems are discussed to show the advantages of the model as compared to more traditional approaches. Additionally, several actual simulations of hypothetical reservoirs are shown and the results are compared with both standard single porosity and dual porosity black oil models currently available. The enhanced representation of the physical system compared to classical black oil models is achieved in a way which is efficient in the use of both the memory and processor resources of the computer, whilst the modular nature of the simulator, coupled with advanced programming and documentation standards, will facilitate its further development and maintenance. 305

No abstract

The form factors of the semi-leptonic decays K"*"->• Tr^e"*"!» and K"*"->•-n^ii^v have been investigated using a sample of events detected in the CERN 1.1 m^ heavy liquid bubble chamber. Analyses have been carried out using methods indépendant of any assumption of the q dependence of the form factors in addition to the usual linear parametrizations. Consistent results have been obtained from separate studies of both Dalitz plot density distributions and the branching ratio. A parametrized global analysis of both decay modes gives the values ï(0) =-1.3 ± 0.7 and Ç(4.4M^)=-0.45 ± 0.13, or \ =-0.017 ± 0.011 both for a fitted value of X+ = 0.025 ± 0.007. K^a-AV K^j-TrOeV KJJ-TTV»', K^j-Tr^e^.. I-* Chercheur agréé à l'IISN, Belgique. ** Erkend onderzoeker by het IIKW, België. w. * This is désirable in order to check the validity of the lineai expansions, especially as laige corrélations exist between the parameters. The depth of the chamber was later increased to 110 cm, increasing the visible volume by a factor of three. See e.g. Young [4]. * The upper limit éliminâtes the influence of bremsstrahlung 7-rays.

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe viability of miscible WAG injection as an EOR scheme for the Magnus reservoir is under consideration. Performance prediction and optimization under this type of recovery mechanism, in which the residual oil is usually recovered by a multi-contact miscible (MCM) process, rely mostly upon compositional simulation. Unfortunately, numerical dispersion effects, associated with large grid blocks required in field scale compositional simulation of MCM processes, can result in erroneous phase behavior. Reduction of dispersion to acceptable levels may require very small grid blocks, implying model sizes that exceed the capacity of current conventional computer installations. Thus, full field compositional models are not practical for reliable field-wide benefit predictions. This paper presents a systematic procedure that we successfully employed for prediction of field wide performance and recovery benefit of miscible WAG injection for the Magnus reservoir. The procedure involves an extension of the upscaling technique proposed by Fayers et al [1]. It starts with a 3D fine grid compositional sector model of a small representative element of the reservoir. Then, this reference model is upscaled to block sizes corresponding to those in the Magnus full field model (FFM), using the singlephase half-cell upscaling technique. The upscaled model employs the Todd and Longstaff (T&L) formulation [1,2] for simulating MCM displacement and three-pseudo components for representing phase behavior. The PVT, solvent equilibrium constants and miscibility pressure vs. composition tables are developed through matching with a calibrated 12-component equation of state (EOS) and 1D slim tube simulations, for a wide range of pressure and composition. The PVT treatment also allows for vaporization of oil by the contacting gas. We also discuss impacts of various uncertain parameters on the performance of MCM WAG injection, which were investigated using the calibrated upscaled model, taking advantage of about 1000 times gain in CPU time compared to that for the reference fine grid compositional model.