While fabricating micro-models that mimics a carbonate reservoir, synthetic “oil-wetting solid surfaces” and synthetic “high permeable fractures” are introduced to alter the wettability of the solids in EOR processes during spontaneous-imbibition as well as during imposed flow.
How about the up-scaling of such micro-model results to a larger field-scale implementation?
Generally there are a common series steps that you need to do, regardless of type of EOR activities.
They are as follows:
1- Data gathering
2- Numerical modeling
3- Laboratory evaluation. (In your case, micro model)
4- Feasibility studies by updating numerical models based on lab data.
5- Pilot screen criteria and design
6- Pilot evaluation and selection of the injectors
7- First pilot implementation.
8- Comparing pilot results and updating all of engineering and economic models.
9- If the results were promising, then you have to start to re-write the FDP or field development plans. This section is a tricky part, because non-related topics, such as politics and oil market becomes determining factor.
10 - Consequently you might start to do your full field implementation.
Based on what you mentioned above, it seems to me that you are the second or third step of what I mentioned above.
Hope it helps.
Alireza (KJ).
Some of scale up methods from the lab scale to a field scale depend on the dimensionless parameters. Search for which parameter/parameters from these parameters is/are suitable with your method.
Dear Suresh,
Basically, the micro model is used for interpretation of some complex phenomena that may happen in porous media (e.g. wettability alteration, flow regime, ...etc.). Thus, to my knowledge, upscaling of 2D model results yet to be generalized to reservoir scale.
Hello,
As far as I know, people don't usually do it, one big reason being that micromodels are inherently trying to capture two-dimensional features while actual rocks are obviously 3D - the connectivity of each pore, the surface area and other important porous media properties are completely different. Most complex phenomena you observe in a 2D micromodel would probably not behave the same in a 3D system - for example the percolation threshold is different, and so is the near percolation behavior. This would be even more true when wettability is involved. There are ways to circumvent some of these issues, but I don't think I have seen quantitative analyses comparing 2D micromodels with core-scale results, let alone reservoir scale.
I agree with Rahul Verma. Micromodels help us in understanding the pore scale mechanisms and test new theories, however due simplified representation of pore space their results can not be upscaled to field scale.
Is there any solid proof of applicability of fabricated micro-models for mimicking carbonates? Phi, Kabs, Krw, Kro for drainage and imbibition? How is about CA_adv and CA_res?
I agree with Rahul Verma and Harris Rabbani, the micro model is used to interpret some complex phenomena. Due to the process of upscaling, the field scale model may not be practical.
You know that scale up of a process from micro model system to field scale is very complex and must be considered the following step.
1- specify the type of EOR process ( thermal process, microbial process, miscible displacement,......)
2-you need a comprehensive study to your considered EOR process.
3-prepare a list of effective parameters on the selected EOR process,
4-find a set of Dimensionless number (by Pi- theorem method, Hansaker Method,.... or by empirical method)
5-....
6-...,.....
7-.......
.
In my opinion scale up of a process from micro model to field scale is possible if we used a dimensionless model.
I have a successful experience in scale up of permeability decline process due to sulfate scale formation in glass micro mole system to sand packed and core scale. In my experience a dimensionless model have been used for prediction of permeability reduction due mineral scale deposition from micro model to sandstone core scale.
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