It is a routine approach that production logging tool (PLT) data are used to match and find the best correlations for well flowing model in oil&gas fields.
My question is to understand whether it's possible to use a reservoir simulator as data generator for well flow modeling. If this is feasible, the expensive, time-consuming PLT test can be simulated to select the best model for a given reservoir
I'm having a serious confusion.
PLT data is used to calibrate the simulation model time to time to achieve good history match. Then why you are going to achieve the reverse scenario.
Coming to your question:
Does your model shows good history match even at well level? And how you've done upscaling of the geological model, i.e. perforations are well defined with vertical layering?
If you've got very good well level prediction and upscaling of grid is in accordance if geology then theoretically it could be done provided there is no change in the dynamics of the system.
In CMG it can be done. Make the grid as per the Flow Zone modelling. Up load the pressure production data and assign well head pressure date wise in event.
It may help.
Thank you. About the reason to do a reverse scenario, I am going to test the capability of a simulator to produce production data throughout a well and compare performance of different well Tubing performance relationship (TPR) models
The problem I've faced with is that the simulator predictions are not in accordance with PLT data. That is, the simulator predictions follow the fluid hydrostatic pressure in the cells which well crosses. This is not the case in PLT data.
Do you have any suggestion?
As far as I know, well testing data is used to predict the well flowing model. Well testing can be up-scaled for the whole reservoir, or at least for an appropriate region of the reservoir. But PLT data is highly limited to a well and cannot be modified properly to a reservoir as wellbore wall completely differs from well to well.
Its very tricky and cumbersome. How many wells you are having?
For each well try to put different perforation interval in different vertical cells. You can do this by using cell modifier (Make the grid finer around each well).
Limit the range of the modifier as per the drainage area of each well. Drainage area of each well can be found from PTA (Pressure Transient Analysis) or Production Decline Analysis.
But this is very cumbersome process. If the number of wells are sufficiently high and their drainage area interferes with each other then degree of difficulty will be spiked up by several notches.
Try this, you may get success.
I think there can be a solution to generate the well production data similar to PLT in the lack of available field PLT data. But our current approach to the problem gives pressure versus depth results in accordance with hydrostatic pressure gradient. On the other side, the PLT reports contain exact contribution of each layer to a specific well.
Does any one have an idea how to solve this issue?
Sure, this kind of data generation is the bread and butter of those who work with STARS model.
Reza,
I am not sure which software you are using. In most dynamic simulators you can actually create an array to save in it the saturaion and pressure of each layer at each time step. Once you know the sarurations and their change you can calculate recovery factor per layer during certain time peroid. If you have that for each layer then the remaning is normalizing with por volume and ratio based on your well production rate. The height and porosity of each layer is there and you can do the calculation in one go depending on your simulator.
Reza,
Please try this keyword: WRFTPLT. It exports both RFT and PLT data. Search in the manual what it exports and what you need to specify. As far as I remember it is in the schedule section.
Khaldoon answer refers to ECLIPSE. Similar keywords exist in all commercial and most R&D simulators.
That is right Dr. Pierre. So, Dr. Reza mentioned that he is using Eclipse 300, Thanks.
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