Development Of Complex Layered And Fractured Reservoir Models For Reservoir Simulation

dc.creatorCorreia
dc.creatorManuel Gomes; Maschio
dc.creatorCelio; Schiozer
dc.creatorDenis Jose
dc.date2017
dc.datejan
dc.date2017-11-13T13:23:46Z
dc.date2017-11-13T13:23:46Z
dc.date.accessioned2018-03-29T05:56:22Z
dc.date.available2018-03-29T05:56:22Z
dc.identifierJournal Of The Brazilian Society Of Mechanical Sciences And Engineering. Springer Heidelberg, v. 39, p. 219 - 233, 2017.
dc.identifier1678-5878
dc.identifier1806-3691
dc.identifierWOS:000389988800016
dc.identifier10.1007/s40430-016-0606-7
dc.identifierhttps://link-springer-com.ez88.periodicos.capes.gov.br/article/10.1007%2Fs40430-016-0606-7
dc.identifierhttp://repositorio.unicamp.br/jspui/handle/REPOSIP/328167
dc.identifier.urihttp://repositorioslatinoamericanos.uchile.cl/handle/2250/1365192
dc.descriptionThe link between the geostatistical modeling of multiscale carbonate heterogeneities and representative simulation flow models remains a challenge because conventional upscaling procedures often disregard the complex dynamic behavior that links the geostatistical static properties, dynamic rock/fluid data and reservoir operational conditions. This work proposes a methodology to build robust simulation models for naturally fractured carbonate reservoirs with multiscale geological characterizations. The development of this work follows three main steps: (1) hierarchical upscaling procedure by flow units, (2) integration of flow units into a reservoir-scale simulation model, (3) validation of simulation model. The hierarchical upscaling procedure was applied to three inter-well regions and extrapolated to three flow units. The proposed workflow is applied to a reservoir based on a combination of real and synthetic data from a Brazilian offshore carbonate reservoir. The methodology shows several advantages: it represents static and dynamic behavior from multiscale heterogeneities in reservoir simulation; it minimizes risk in the selection of well position and completion through well characterization of representative static and dynamic data for each flow unit; and, improved selection process for the simulation flow model. The methodology shows that the relative permeability defined in reservoir simulation can be different from the laboratory measured curve because it needs to match the dynamic behavior from the reference solution. This result shows that a proper characterization and upscaling approach are crucial to sufficiently represent geological heterogeneous scenarios in reservoir simulation. The methodology we present here is useful for multidisciplinary areas of expertise as it ensures the appropriate link between the fine scale geomodelling and the coarser scale reservoir simulation, considering the development of complex carbonate reservoirs.
dc.description39
dc.description1
dc.description219
dc.description233
dc.descriptionCenter of Petroleum Studies (Cepetro-Unicamp/Brazil)
dc.descriptionPETROBRAS S/A, UNISIM
dc.descriptionPetroleum Engineering Department (DEP-FEM-Unicamp/Brazil)
dc.descriptionSchlumberger Information Solution for the use of Petrel(R), and CMG for the use of IMEX
dc.languageEnglish
dc.publisherSpringer Heidelberg
dc.publisherHeidelberg
dc.relationJournal of the Brazilian Society of Mechanical Sciences and Engineering
dc.rightsfechado
dc.sourceWOS
dc.subjectCarbonate Reservoir
dc.subjectDual Porosity
dc.subjectMultiscale Heterogeneities
dc.subjectReservoir Simulation
dc.titleDevelopment Of Complex Layered And Fractured Reservoir Models For Reservoir Simulation
dc.typeArtículos de revistas


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