Page 1 of 3 1 2 3 LastLast
Results 1 to 12 of 31
  1. Question to simulation engineers!

    I am working in field with huge lateral extent. there are no separation faults to make compartments nor geological bodies to separate and compartmentalize the field.

    however,one thing I notices is the change in PVT properties mainly viscosity is drastic !

    ranges from just 1 cp in the west to 20 cp on the east.and the other PVT are almost identical.

    so,can I consider the field as one PVT region or should I make subdivisions based only on one PVT property?

    waiting for your contributions


    See More: Question to simulation engineers!

  2. # ADS
    Spons Circuit
    Join Date
    Always
    Posts
    Many
     
  3. #2

    Join Date
    Dec 2008
    Location
    Venezuela
    Posts
    44
    One way:
    you may divide your model in 4 or 5 pvt regions, according to API variation. then you need to define a pvt table for each region. The only problem is when the fluid migates from one region to other it wil change its properties automatically.

  4.    Sponsored Links



    -

  5. #3
    Use more than 1 region and accordingly pvt tables for each region. Now it depends on you how many regions you define for a reservoir

  6. #4

    Join Date
    Nov 2008
    Location
    Australia
    Posts
    508
    Suggest that you first try to understand the physical significance of your observations.... what's causing the properties to vary so much in an ostensibly homogeneous system? Perhaps it is not as homogeneous as you think? Could it be related to change of depth/temp over that areal extent?
    Last edited by vinomarky; 03-13-2010 at 03:26 PM.


  7.    Spons.


  8. #6

    Join Date
    Feb 2009
    Location
    trinidad and tobago
    Posts
    9
    please how do i solve this problem?


    @ LINEAR EQUATIONS NOT FULLY CONVERGED - RUN MAY GO FASTER
    @ IF YOU INCREASE LITMAX (= 25 - TUNING KEYWORD)

    @--PROBLEM AT TIME 1657.8 DAYS (15-JLY-2004):
    @ NON-LINEAR EQUATION CONVERGENCE FAILURE
    @ ITERATION LIMIT REACHED - TIME STEP CHOPPED FROM 23.41

    My threads; perezo :


    • #7
      ahem... try to increase Newton iterations number or something like that in the numerical parameters of your simulator (have a look at the "numerics" section in the user's guide of your reservoir simulator); and/or decrease the time step (keep it constant and very very small); and/or relax the material balance criteria
      Last edited by totor; 03-16-2010 at 04:27 PM.


    • Quote Originally Posted by vergatario View Post
      One way:
      you may divide your model in 4 or 5 pvt regions, according to API variation. then you need to define a pvt table for each region. The only problem is when the fluid migates from one region to other it wil change its properties automatically.
      the API is identical for the whole reservoir the variation is just on viscosity !

    • Quote Originally Posted by 06pg22 View Post
      Use more than 1 region and accordingly pvt tables for each region. Now it depends on you how many regions you define for a reservoir
      the problem is that : the reservoir is shared by more than one company,and the objective of the simulation is to prove the communication and calculate the oil migrated.in history match phase the field was proved to have been in communication with two PVT regions .And now i use single PVT region there is more oil migration and better history match,but the other companies still arguing of using more PVT regions! what should I do?

    • Quote Originally Posted by vinomarky View Post
      Suggest that you first try to understand the physical significance of your observations.... what's causing the properties to vary so much in an ostensibly homogeneous system? Perhaps it is not as homogeneous as you think? Could it be related to change of depth/temp over that areal extent?
      you are right to some extent!

      in the measurements there are some sort of scatter variations, but as general observation (average values) there are one region with viscosity around 10 cp and another one with viscosity around 20 and the WOC difference between theses regions is about 90 ft.
      One interesting point I noticed is that the region of 20 cp is the only part of the model which doesn't have aquifer support!

      waiting for your comments

    •    Spons.


    • #12

      Join Date
      Dec 2008
      Location
      Venezuela
      Posts
      44
      A good tool to prove comunication is to use geochemist analysis. You have take samples of fluids in several points (for instance one ell of your company and other sample in a well of ther company). They generate a kind of diagram for each of the samples and later it can be said if the oil is the same. you can propose that.

    •   

    Similar Threads

    1. Replies: 2
      Last Post: 03-07-2013, 09:19 PM
    2. Reservoir simulation exam question help!!!!
      By emrah76 in forum Reservoir
      Replies: 5
      Last Post: 01-21-2012, 06:15 PM
    3. Replies: 3
      Last Post: 05-14-2011, 09:04 PM
    4. Replies: 1
      Last Post: 03-01-2011, 01:27 AM
    5. Question to simulation engineers!
      By Alamen Gandela in forum Home Articles
      Replies: 2
      Last Post: 04-04-2010, 09:44 AM

    Tags for this Thread

    Bookmarks

    Posting Permissions

    • You may not post new threads
    • You may not post replies
    • You may not post attachments
    • You may not edit your posts
    •