Abstract
Characterisation of the fractured reservoirs is of great importance as reservoirs of this type represent a significant proportion of the aquifers and petroleum reservoirs in the world. Well test is one of the main tools for this purpose. Inter-porosity fluid exchange coefficient is one of the parameters that should be determined in this kind of reservoirs as a result of well test. This paper investigates the inter-porosity fluid exchange coefficient inferred from well test in non-uniformly distributed fractured reservoirs through numerical fracture network and flow modelling. Here, we examine the impact of the fracture distribution and pumping well location on the reservoir hydrodynamic response during a well test by numerical simulation. To do so, several synthetic fractured models are prepared by use of a commercial geo-modeller. Numerous well tests are simulated in these models and their hydrodynamic responses to the pumping well are recorded and interpreted applying classical methods of well test interpretation in fractured reservoirs. Finally the inferred inter-porosity fluid exchange coefficients are compared; it is shown that, in a non-uniformly fractured system, this coefficient value is highly dependent on the fracture distribution pattern, pumping well location and its connectivity to the flow-path network. Consequently, we demonstrate that the standard and classic methods of the average matrix bock dimension estimation by well test may be very sensitive to the pattern of fracture distribution (uniform or non-uniform). • Inter-porosity fluid exchange coefficient inferred from well test is studied. • It is done in non-uniformly distributed fractured reservoirs by numerical simulation. • This coefficient value is highly dependent on the fracture distribution pattern. • It is relative to pumping well location and its connectivity to flow-path network.
Published Version
Talk to us
Join us for a 30 min session where you can share your feedback and ask us any queries you have
Schedule a call