Factoring Permeability Anisotropy in Complex Carbonate Reservoirs in Selecting an Optimum Field Development Strategy

Current methods of oil and gas field development design rely on reservoir simulation modeling. A model is a tool to reproduce processes forecast production data. Reservoir permeability one the basic properties that determines fluid flow. From existing approaches, porosity values should be consistent with petrophysical correlations obtained from core sample tests in course an absolute cube model. For carbonate reservoirs complex pore space structure fractures, are often unstable. To factor flow fractured rock system, dual-medium models developed, allowing for matrix fracture components. Yet this case, degree uncertainty only increases introduction new parameter: cross-flow index migration fracture, which determined indirectly by results studies conducted initial period, therefore most adaptive. Clearly, well-studied fields there extensive data pool drawn research findings: studies, well logging, testing, flowmetry, special well-logging (FMI, Sonic Scanner, etc.); such fairly well-founded supported actual studies. However, at start development, incomplete, renders qualitative modeling impossible. This paper proposes approach target’s anisotropy early stage through integration well, 3D seismic surveys. The was classified into types, different were assigned develop array, relative phase permeabilities studied. history-matched allowance types. Comparative calculations resulting select optimum strategy target.