[Opm] Problem with injecting field voidage replacement
Bao Kai
paeanball at gmail.com
Fri Mar 15 11:21:50 UTC 2019
I forgot to reply the message to the OPM mailing lists. Just forward
the reply here.
---------- Forwarded message ---------
From: Bao Kai <paeanball at gmail.com>
Date: Fri, Mar 15, 2019 at 10:51 AM
Subject: Re: [Opm] Problem with injecting field voidage replacement
To: Stephen, Karl D <K.D.Stephen at hw.ac.uk>
Hi, Stephen,
Thanks for the message and all the efforts to create this case and
provide the DATA file.
I have not been able to run the deck, while this is some inputs from my side.
Group control is very general and flexible, we currently only support
very limited subset of the features related to group control based on
our project requirements. We will have continuous efforts to complete
and improve the group control functionality when we can allocate
resources.
As for your deck, we do not support one group to obtain voidage rate
based on the production rate from another group, and also, we
understand it is not very trivial to fix based on the current
implementation.
We have an example in opm-tests to demonstrate what features related
to group control we are supporting,
https://github.com/OPM/opm-tests/tree/master/spe9group .
Please take a look at this example to see whether you can change your
group structure a little bit (similar to the example spe9group) and
also fulfill your purpose. Please let me know if you need any help
for it.
Hope it is helpful to you.
Best Regards,
Kai Bao
On Fri, Mar 15, 2019 at 2:05 AM Stephen, Karl D <K.D.Stephen at hw.ac.uk> wrote:
>
> Hi,
> I have a problem with a simple quarter 5 spot waterflood model where I would like to inject water with field voidage replacement. There are two wells: injector, INJ, and producer, PROD. I would hope that the field voidage replacement takes the production rate in reservoir volumes and uses that to inject water at the same reservoir volumetric rate. If the injection and production volumes are the same the field average pressure, FPR, should be relatively constant.
>
> The problem I have is that while the reported FVIR and FVPR are the same and the FWIR seems to be right as is the sum of FOPR and FWPR, the FPR (average pressure) does not remain relatively constant. Instead there is a drift as if the actual volumes injected and produced are different.
>
> The problem seems to be to do with the definition of the formation volume factor for water, Bw, that is defined in the PVTW keyword. Bw is defined at a reference pressure which is the same as the initial average pressure. If it is 1.0 exactly then the hoped for result is obtained. If I use a more realistic value of 1.02, the volumes are incorrect and FPR eventually rises when water breaks through. Similarly if Bw is set to 0.99, the pressure goes down. I have deliberately set the compressibility of water to be very small and in PVDO, the Bo (formation volume factor for oil) is almost independent of pressure (when I started, Bo and Bw were dependent on pressure).
>
> Perhaps I am doing something wrong with the keywords, there is a setting I need to implement or is there a a bug in the code?
>
> Can anyone help?
>
> I attach my code for analysis.
>
> Using Eclipse I can get a good result. I set up the well controls with:
>
> - GRP Fluid Control Surf Resv ReInj Voidage GRUP
> -- NAME TYPE mode rate rate frac Frac CNTL
> -- ---- ----- ------ ------- ---- ---- ---- ---- -----
> GCONINJE
> FIELD WATER VREP 15000 2* 1.0 NO /
> /
> -- Injection control
> -- Well Fluid Status Control Surf Resv BHP
> -- NAME TYPE mode rate rate limit
> -- ---- ----- ------ ------- ---- ---- -----
> WCONINJE
> INJ WATER OPEN GRUP 15000 1* 8000 /
> /
>
>
> This doesn't work in OPM where I have to add the group control for my injector, INJ.
>
> - GRP Fluid Control Surf Resv ReInj Voidage GRUP
> -- NAME TYPE mode rate rate frac Frac CNTL
> -- ---- ----- ------ ------- ---- ---- ---- ---- -----
> GCONINJE
> FIELD WATER VREP 15000 2* 1.0 NO /
> G2 WATER VREP 15000 2* 1.0 YES / -- THIS IS EXTRA!!!!!!!!
> /
> -- Injection control
> -- Well Fluid Status Control Surf Resv BHP
> -- NAME TYPE mode rate rate limit
> -- ---- ----- ------ ------- ---- ---- -----
> WCONINJE
> INJ WATER OPEN GRUP 15000 1* 8000 /
> /
>
>
> Karl Stephen
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