distribution of formation...
TRANSCRIPT
What properties to distribute for reservoir
simulation?
• Gross thickness
• Net reservoir thickness
• Absolute permeability
• Effective porosity
• Other: shale beds, fractures…
Use of geologic model data in reservoir simulation
Property Use in Simulation Status
Structure top Reservoir depth
Initial reservoir pressure
Original oil in place (OOIP) and original gas in
place (OGIP) calculations
Required for top layer
Net reservoir thickness, hn Assignment of cell net thickness values
Horizontal-transmissibility calculations
PV calculations
Calculation of well geometric factors, Gw
OOIP and OGIP calculations
Required
Gross reservoir thickness, hg Assignment of cell gross thickness values
Gravity head calculations
Initial reservoir pressures
Transition-zone calculations
Initial saturation distributions
Vertical-transmissibility calculations
Optional (default may be obtained from net
thickness)
Net-to-gross ratio Assignment to cell hn/hg values Optional(default may equal one, hn/hg=1)
Porosity Assignment of cell values
Development of porosity/permeability transforms
Pore volume (PV) calculations
OOIP and OGIP calculations
Required for all layers
Horizontal permeability Assignment of cell permeability values
Horizontal-transmissibility calculations
Development of porosity/permeability transforms
Calculation of well geometric factors, Gw
Required for all layers
Vertical permeability Assignment of cell permeability values
Vertical-transmissibility calculations
Optional(default may be obtained from kv/kh=1)
Initial saturations Initial saturation distributions
Transition-zone heights
OOIP and OGIP calculations
Optional(default may be obtained from Pc data)
Endpoint saturations Saturation normalization
Assignment of cell critical saturation values for
saturation unnormalization
Optional(default may be obtained from kr curves)
Fluid Contacts OOIP and OGIP calculations
Initial saturation distributions
Initial reservoir pressures
Required
Porosity AveragingPorosity - thickness-weighted average
n
ii
h
n
ii
hi
1
1
h1
h2
h3
1
2
3
Water saturation - volume weighted average
n
i
n
iw
S
1i
hi
φ
1i
hi
φwi
S
Measures of Heterogeneity
50
1.8450
k
kkV
ADCAArea
ABCAAreak
L
Dyksta-Parsons Coefficient Lorenz Coefficient
Pitfalls of statistical approaches
• Data in sequential order…reservoir is not
• relies on permeability variations for estimating
layers, however the speed of fluid traveling
through a layer is dependent on the phase
mobility, pressure gradient, and the k/ ratio.
dep
th
arranged un-arranged
Hydraulic Flow Unit
}{0314.0}{
mdkmRQI
zk
gvS
FZI1
1r
0.010
0.100
1.000
10.000
0.010 0.100 1.000
Porosity Ratio
RQ
I
How?
Porosity-Permeability Transforms
1E-03
1E-02
1E-01
1E+00
1E+01
1E+02
1E+03
1E+04
0.00 0.05 0.10 0.15 0.20 0.25 0.30 0.35
porosity
pe
rme
ab
ilit
y
Core Porosity vs Permeability
0.1
1
10
100
1000
0.0 5.0 10.0 15.0 20.0 25.0 30.0 35.0
Porosity
Pe
rm
eab
ilit
y, m
d
Clastic example:
Burbank Sandstone, Oklahoma
Carbonate example:
San Andres, West Texas
Good Bad
Geostatistics
Kriging
Conditional Simulation
Distributed Values
Data Points
k, Sw, , Net Pay, Gross
Variogram
Model
Poor Example: Final isotropic permeability
distribution after history matching
Note: “bullseye effect”
3D Seismic: Anticlinal Structure - North Field, Qatar: Recoverable
reserves 500 trillion ft3. Largest single accumulation of unassociated
gas in the world.
Application of seismic data