Whether the approximation on the estimation of reservoir location from the well
to be roughly around 61% of the drainage radius
is valid
only for a sandstone reservoir?
Or
If the same approximation cannot be extended to a fractured carbonate reservoir, then,
what should be the rough fraction of the drainage radius
that should be considered
for steady-state flow condition?
In general, each reservoir is unique in some way due to its geological components: porosity, permeability, seal quality, structural integrity and both the quantity and quality of hydrocarbons present. That said, I wouldn't assume any location from the well as a percentage of an alleged drainage radius...there are too many variables to be considered, irrespective of the reservoir being clastic or carbonate. High quality 3D seismic data in conjunction with extraction of seismic attributes could possibly give you a better approximation.
Also, natural fractures, which are part of the secondary porosity, can be classified as tectonic, regional and diagenetic, following the Aguilera's concepts, 1988.
Thinking that there are a complexity in the petroleum system, and our tools such as 3D seismic illumination, sometimes have been left behind, due that our poor nowledge and description methodology of those reservoirs. It means, our lack of knowledge and our quantitative models.
So, I suggest as Sharon said before, the integration of all existing information at several scales such as drilling, well loging, surface seismic, microseismic, well testing, and so on, to provide a better reservoir description, and for a better estimation about your drainage radius even sandstones (I think is best scenario) or other type of rocks. These combination make data analysis a science.
Also, I suggest to you Numerical Simulation, such as math model to predict fluid-flow and estimate the drainage radius.
best wishes Suresh,
Mario E. Sigismondi
- Badges
- Science topic
- Similar topics
- Geoscience
- Atmospheric Sciences
- Climate Science
- Climate Change