This model has a sufficiently fine grid to make use of classical pseudoisation methods almost impossible. The model has a simple geometry, with no top structure or faults. The reason for this choice is to provide maximum flexibility in choice of upscaled grids.
At the fine geological model scale, the model is described on a regular cartesian grid. The model dimensions are 1200 x 2200 x 170 (ft). The top 70 ft (35 layers) represents the Tarbert formation, and the bottom 100 ft (50 layers) represents Upper Ness. The fine scale cell size is 20 ft x 10 ft x 2 ft.
The model consists of part of a Brent sequence. The model was originally generated for use in the PUNQ project. The top part of the model is a Tarbert formation, and is a representation of a prograding near shore environment. The lower part (Upper Ness) is fluvial.
Fig.1(a) shows the porosity for the whole model, and Fig.1(b) shows part of the Upper Ness sequence, with the channels clearly visible.
The fine scale model size is 60 x 220 x 85 cells (1.122x106 cells).
Figure 1 (a)
Figure 1 (b)
cw= 3.10-6 psi-1
viscosity 0.3 cp
krw(S) = (S*)2
kro(S) = (1-S*)2
S*= (S - Swc) / (1 - Swc - Sor )
Swc = Swi = 0.2
Sor = 0.2
krw(Sor) = kro(Swc) = 1.0
|p (psi)||Bo||viscosity (cp)|
Upscale Initial pressure 6000 psi. Initial depth 12000 ft.
|surface densities:||oil 53 lb/ft3
water 64 lb/ft3
|rock compressibility:||10-6 psi-1|
All wells vertical. All wells completed throughout formation.
Central Injector. Injection rate 5000bbl/day (reservoir conditions). Max injection bottom hole pressure 10000 psi.
4 producers. Produce at 4000psi bottom hole pressure.
|well name||X location||Y location|
|Injection Well I1||600||1100|
|Production Well P1||0||0|
|Production Well P2||1200||0|
|Production Well P3||1200||2200|
|Production Well P4||0||2200|
Upscale the fine scale reservoir description to a suitable coarse grid. Any method of upscaling (single or multi-phase) can be used. Construct a coarse simulation model and simulate 2000 days of production.
To make fair comparisons between the different approaches, we need the following items to be reported:
Simulator used; impes or implicit; timestep strategy (max dt, impes stability on or off, etc).
Inj Well Prod Wells: bottom hole pressure oil rate, watercut, cumulative oil produced
average pressure, oil rate, cumulative oil production, watercut
bottom hole pressure
oil rate, watercut, cumulative oil produced
|Right-click links and "Save Link As..." or "Save Target As..." to download.
Download relative permeability table. (.txt)
Download porosity and permeability file - por_perm_case2.zip (18.4MB)
|Contains:||File 1:||Porosity (60 x 220 x 85)|
|File 2:||Kx (i,j,k), i = 1,60, j = 1,220 k = 1,85
Ky (i,j,k), i = 1,60, j = 1,220 k = 1,85
Kz (i,j,k), i = 1,60, j = 1,220 k = 1,85