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Upscaling of Geocellular Models for Flow Simulation
Louis J. Durlofsky
Department of Petroleum Engineering, Stanford University
ChevronTexaco ETC, San Ramon, CA
2
Acknowledgments
• Yuguang Chen (Stanford University)
• Mathieu Prevost (now at Total)
• Xian-Huan Wen (ChevronTexaco)
• Yalchin Efendiev (Texas A&M)
(photo by Eric Flodin)
3
• Issues and existing techniques
• Adaptive local-global upscaling
• Velocity reconstruction and multiscale solution
• Generalized convection-diffusion transport model
• Upscaling and flow-based grids (3D unstructured)
• Outstanding issues and summary
Outline
4
Requirements/Challenges for Upscaling
• Accuracy & Robustness
– Retain geological realism in flow simulation
– Valid for different types of reservoir heterogeneity
– Applicable for varying flow scenarios (well conditions)
• EfficiencyInjector
Producer
Injector
Producer
5
Existing Upscaling Techniques
• Single-phase upscaling: flow (Q /p)
– Local and global techniques (k k* or T *)
• Multiphase upscaling: transport (oil cut)
– Pseudo relative permeability model (krj krj*)
• “Multiscale” modeling
– Upscaling of flow (pressure equation)
– Fine scale solution of transport (saturation equation)
6
Local Upscaling to Calculate k*
• Local BCs assumed: constant pressure difference
• Insufficient for capturing large-scale connectivity in highly heterogeneous reservoirs
or
Local Extended Local Solve (kp)=0 over local region
for coarse scale k * or T *
Global domain
7
A New Approach
• Standard local upscaling methods unsuitable for
highly heterogeneous reservoirs
• Global upscaling methods exist, but require global
fine scale solutions (single-phase) and optimization
• New approach uses global coarse scale solutions to determine appropriate boundary conditions for local k* or T * calculations
– Efficiently captures effects of large scale flow
– Avoids global fine scale simulation
Adaptive Local-Global Upscaling
8
Adaptive Local-Global Upscaling (ALG)
Well-driven global coarse flow
• Thresholding: Local calculations only in high-flow regions (computational efficiency)
y
x
Coarse scale properties
k* or T * and upscaled well index
Local fine scale calculation
Interpolated pressure
gives Local BCs
Coarse pressure
Local fine scale calculation
Interpolated pressure
gives local BCs
Coarse pressure
9
Thresholding in ALG
Permeability Streamlines Coarse blocks
Regions for
Local calculations
• Avoids nonphysical coarse scale properties (T *=q c/p c)• Coarse scale properties efficiently adapted to a given
flow scenario
• Identify high-flow region, > ( 0.1)|q c||q c|max
10
Multiscale Modeling
0 cp*k 0 )(
St
Sv
• Solve flow on coarse scale, reconstruct fine
scale v, solve transport on fine scale
• Active research area in reservoir simulation:– Dual mesh method (FD): Ramè & Killough (1991),
Guérillot & Verdière (1995), Gautier et al. (1999)
– Multiscale FEM: Hou & Wu (1997)
– Multiscale FVM: Jenny, Lee & Tchelepi (2003, 2004)
11
Reconstruction of Fine Scale Velocity
0 cp*k 0 )(
St
Sv
Upscaling, global
coarse scale flow
Solve local fine scale(kp)=0
Partition coarse
flux to fine scale
Reconstructed fine scale v
(downscaling)
• Readily performed in upscaling framework
12
Results: Performance of ALG
Averaged fine
Pressure Distribution
Coarse: extended local
Coarse: Adaptive local-global
Channelized layer (59) from 10th SPE CSP
Flow rate for specified
pressure
• Fine scale: Q = 20.86
• Extended T *: Q = 7.17
• ALG upscaling: Q = 20.010.0
5.0
10.0
15.0
20.0
25.0
0 1 2 3 4Iteration
Q
Q (Fine scale) = 20.86
ALG, Error: 4%
Extended local,
Error: 67%
Upscaling 220 60 22 6
15
Results: Multiple Realizations
• 100 realizations conditioned to seismic and well data
• Oil-water flow, M=5
• Injector: injection rate constraint, Producer: bottom hole pressure constraint
• Upscaling: 100 100 10 10
100 realizations
Time (days)
BH
P (
PS
IA)
Fine scale
mean
90% conf. int.
16
Results: Multiple Realizations
Coarse: Purely local upscaling Coarse: Adaptive local-global
Time (days)
BH
P (
PS
IA)
Mean (coarse scale)
90% conf. int. (coarse scale)
Time (days) B
HP
(P
SIA
)
Mean (fine scale)
90% conf. int. (fine scale)
17
Results (Fo): Channelized System
220 60 22 6
Fractional Flow Curve
0
0.2
0.4
0.6
0.8
1
1.2
0 0.2 0.4 0.6 0.8 1PVI
Fo
Fine scale
ALG T *
Extended local T * Flow rates
• Fine scale: Q = 6.30
• Extended T *: Q = 1.17
• ALG upscaling: Q = 6.26
Oil cut from reconstruction
18
Results (Sw): Channelized System
Fine scale Sw (220 60)
Reconstructed Sw from
extended local T * (22 6)
0.5
1.0
0.0
Reconstructed Sw from
ALG T * (22 6)
Fine scale streamlines
19
Results for 3D Systems (SPE 10)
50 channelized layers, 3 wellspinj=1, pprod=0
Typical layers
Upscale from 6022050 124410
using different methods
20
Results for Well Flow Rates - 3D
Average errors
• k* only: 43%
• Extended T* + NWSU: 27%
• Adaptive local-global: 3.5%
21
Results for Transport (Multiscale) - 3D
fine scale
ALG T *
local T * w/nw
standard k*
Producer 1
Fo
PVI
fine scale
ALG T *
standard k*
Producer 2
local T * w/nwFo
PVI
• Quality of transport calculation depends on the accuracy of the upscaling
22
Velocity Reconstruction versus Subgrid Modeling
• Multiscale methods carry fine and coarse grid information over the entire simulation
• Subgrid modeling methods capture effects of fine grid velocity via upscaled transport functions:
- Pseudoization techniques
- Modeling of higher moments
- Generalized convection-diffusion model
23
• Coarse scale pressure and saturation equations of same form as fine scale equations
• Pseudo functions may vary in each block and may be directional (even for single set of krj in fine scale model)
Pseudo Relative Permeability Models
, 0),( ** cc pS kx 0),(
* c
c
StS
xF
)()(
)()(
),( ,=),(
**
*c*
c****
c*
oirowirw
wirwi
icii
o
ro
w
rw
μk+μkμk
Sf
SfFμkk
S
xvx
* upscaled function
c coarse scale p, S
24
Generalized Convection-Diffusion Subgrid Model for Two-Phase Flow
• Pseudo relative permeability description is convenient but incomplete, additional functionality required in general
• Generalized convection-diffusion model introduces new coarse scale terms
- Form derives from volume averaging and homogenization procedures
- Method is local, avoids need to approximate
- Shares some similarities with earlier stochastic approaches of Lenormand & coworkers (1998, 1999)
)()( yx ji vv
25
• Coarse scale saturation equation:
Generalized Convection-Diffusion Model
cccc
SSStS
),(),(
xDxG
),()(),( cccc SSfS xmvxG
• Coarse scale pressure equation:
cccc SSSWS ),(),()( 21* xWx
(modified convection m and diffusion D terms)
(modified form for total
mobility, Sc dependence)
“primitive” termGCD term
0),( ** cc pS kx
26
• D and W2 computed over purely local domain:
Calculation of GCD Functions
p = 1 S = 1
p = 0)()()( SfSfSS vvD
• m and W1 computed using extended local domain:
(D and W2 account for local subgrid effects)
SSSfSfS )()()( )( Dvvm
(m and W1 - subgrid effects due to longer range interactions)
target coarse block
27
Solution Procedure
• Generate fine model (100 100) of prescribed parameters
• Form uniform coarse grid (10 10) and compute k* and directional GCD functions for each coarse block
• Compute directional pseudo relative permeabilities via total mobility (Stone-type) method for each block
• Solve saturation equation using second order TVD scheme, first order method for simulations with pseudo krj
fine grid: lx lz
Lx = Lz
28
Oil Cuts for M =1 Simulations
• GCD and pseudo models agree closely with fine scale (pseudoization technique selected on this basis)
lx = 0.25, lz= 0.01, =2, side to side flow
100 x 100
10 x 10 (GCD)
10 x 10 (primitive)
10 x 10 (pseudo)
Oil
Cu
t
PVI
29
Results for Two-Point Geostatistics
x =0.05, y = 0.01, logk = 2.0
100x100 10x10, Side Flow
10
0
5
• Diffusive effects only
30
Results for Two-Point Geostatistics (Cont’d)
x =0.5, y = 0.05, logk = 2.0
100x100 10x10, Side Flow
10
0
5
• Permeability with longer correlation length
31
Effect of Varying Global BCs (M =1)
p = 1 S = 1
p = 0
0 t 0.8 PVI
p = 1 S = 1 t > 0.8 PVI
p = 0
lx = 0.25, lz= 0.01, =2
Oil
Cu
t
PVI
100 x 100
10 x 10 (GCD)
10 x 10 (primitive)
10 x 10 (pseudo)
lx = 0.25, lz= 0.01, =2
32
Corner to Corner Flow (M = 5)
100 x 100
10 x 10 (GCD)
10 x 10 (pseudo)
Oil
Cu
t
PVIT
ota
l Ra
tePVI
lx = 0.2, lz= 0.02, =1.5
• Pseudo model shows considerable error, GCD model provides comparable agreement as in side to side flow
33
Effect of Varying Global BCs (M = 5)
100 x 100
10 x 10 (GCD)
10 x 10 (pseudo)
Oil
Cu
t
PVIT
ota
l Ra
tePVI
lx = 0.2, lz= 0.02, =1.5
• Pseudo model overpredicts oil recovery, GCD model in close agreement
34
Effect of Varying Global BCs (M = 5)
lx = 0.5, lz= 0.02, =1.5
• GCD model underpredicts peak in oil cut, otherwise tracks fine grid solution
100 x 100
10 x 10 (GCD)
10 x 10 (pseudo)
Oil
Cu
t
PVIT
ota
l Ra
tePVI
35
),( * cc SS
0 ** cpkCoarse scale flow:
Pseudo functions:
GCD model:
T * from ALG, dependent on global flow
*, m(S c) and D(S c)
• Consistency between T * and * important for highly
heterogeneous systems
Combine GCD with ALG T* Upscaling
)( * cS
36
ALG + Subgrid Model for Transport (GCD)
t < 0.6 PVI t 0.6 PVI
• Stanford V model (layer 1)
• Upscaling: 100130 1013
• Transport solved on coarse scale
flow rate oil cut
37
flow simulation flow simulation
upscaling
gridding
diagnostic
GocadGocadinterface
coarse model
info. maps
fine model
Unstructured Modeling - Workflow
38
Numerical Discretization Technique
• CVFE method: – Locally conservative; flux on a face expressed as linear
combination of pressures
– Multiple point and two point flux approximations
• Different upscaling techniques for MPFA and TPFA
i j
k
qij = a pi + b pj + c pk + ... or qij = Tij ( pi - pj )
Primal and dual grids
39
3D Transmissibility Upscaling (TPFA)
Dual cells Primal grid connectionp=1
p=0fitted extended regions
cell j cell i
Tij*= -<qij>
<pj> <pi>-
40
Grid Generation: Parameters
• Specify flow-diagnostic
• Grid aspect ratio
• Grid resolution constraint:
– Information map (flow rate, tb)
– Pa and Pb , sa and sb
– N (number of nodes)
min max
1
property
cumulative frequency
a b
Pa
Pb
min max
Sa
Sb
property
resolution constraint
a b
42
Flow-Based Upscaling: Layered System
• Layered system: 200 x 100 x 50 cells
• Upscale permeability and transmissibility
• Run k*-MPFA and T*-TPFA for M=1
• Compute errors in Q/p and L1 norm of Fw
p=0p=1 1 0. 5
0.25
43
Flow-Based Upscaling: Results
0 0.2 0.4 0.6 0.8 10
0.2
0.4
0.6
0.8
1
PVI
Reference (fine)TPFAMPFA
8 x 8 x 18 = 1152 nodes 6 x 6 x 13 = 468 nodes
0 0.2 0.4 0.6 0.8 10
0.2
0.4
0.6
0.8
1
Fw
error in Fw error in Q/p
TPFA 7.6% -1.2%
MPFA 17.9% -25.2%
error in Fw error in Q/p
TPFA 16.8% -5.9%
MPFA 21.3% -31.7%
PVI
Fw
(from M. Prevost, 2003)
44
Layered Reservoir: Flow Rate Adaptation
• Grid density from flow rate
log |V| grid size
sb
sa
0 0.2 0.4 0.6 0.8 10
0.2
0.4
0.6
0.8
1
PVI
Fw
referenceuniform coarse (N=21x11x11=2541)
flow-rate adapted (N=1394)
Qc=0.82
Qc=0.99
PVI
Fw
• Flow results
(from Prevost, 2003)
(Qf = 1.0)
45
Summary
• Upscaling is required to generate realistic coarse scale models for reservoir simulation
• Described and applied a new adaptive local-global method for computing T *
• Illustrated use of ALG upscaling in conjunction with multiscale modeling
• Described GCD method for upscaling of transport
• Presented approaches for flow-based gridding and upscaling for 3D unstructured systems
46
Future Directions
• Hybridization of various upscaling techniques (e.g., flow-based gridding + ALG upscaling)
• Further development for 3D unstructured systems
• Linkage of single-phase gridding and upscaling approaches with two-phase upscaling methods
• Dynamic updating of grid and coarse properties
• Error modeling