Study of Waterflooding Process in Naturally Fractured Reservoirs from Static and Dynamic Imbibition...
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Study of Waterflooding Process in Naturally Fractured Reservoirs from Static and Dynamic Imbibition Experiments E. Putra, Y. Fidra and D.S. Schechter SCA9910
Study of Waterflooding Process in Naturally Fractured Reservoirs from Static and Dynamic Imbibition Experiments E. Putra, Y. Fidra and D.S. Schechter SCA9910
Study of Waterflooding Process in Naturally Fractured
Reservoirs from Static and Dynamic Imbibition Experiments E. Putra,
Y. Fidra and D.S. Schechter SCA9910
Static imbibition Dynamic imbibition Field dimension Determine
rock wettability Upscaling Determine laboratory critical injection
rate Fracture Capillary Number Scaling equations Capillary pressure
curve Capillary pressure curve Introduction
Slide 4
Objectives To investigate wettability of Spraberry Trend Area
at reservoir conditions. To investigate the contribution of the
capillary imbibition mechanism to waterflood recovery. To determine
the critical water injection rate during dynamic imbibition.
Slide 5
Slide 6
Experimental Set-up for Static Imbibition Tests at Ambient
Conditions
Slide 7
Experimental Set-up for Static Imbibition Tests at Reservoir
Conditions
Slide 8
Slide 9
Effect of Pressure and Temperature on Static Imbibition in
Berea Sandstone
Slide 10
Effect of Temperature on Static Imbibition with Spraberry
Reservoir Rock
Slide 11
Displacement A B Static imbibition Wettability index vs aging
time for different experimental temperatures Spraberry cores
Slide 12
Slide 13
C = 10.66 ; Scaling Equations for Static Imbibition
Slide 14
Up-scaled Recovery Profile L s = 3.79 ft h = 10 ft 1U Upper
Spraberry 1U Formation (Shackelford-1-38A)
Slide 15
Effect of Matrix Permeability and Fracture Spacing on Oil
Recovery
Slide 16
Static Imbibition Modeling Brine Core plug Glass funnel Oil
bubble Oil recovered Governing Equation No gravity effect Only Pc
as driving force Fluid and rock are incompressible Assumptions
Slide 17
Capillary Pressure Curves Obtained as a Result of Matching
Experimental Data Static Imbibition Modeling Match between
Laboratory Experiment and Numerical Solution for S or = 0.2
Slide 18
Water Oil Invaded Zone Matrix Fracture Matrix Counter-current
Exchange Mechanism Concept of Dynamic Imbibition Process
Slide 19
Matrix Fracture Artificially fractured core Air Bath Core
holder Brine tank Confining pressure gauge Graduated cylinder N 2
Tank (2000 psi) Ruska Pump Experimental Set-up for Dynamic
Imbibition Tests at Reservoir Temperature
Slide 20
Oil Recovery from Fractured Berea and Spraberry Cores during
Water Injection using Different Injection Rates
Slide 21
Comparison between Static and Dynamic imbibitions for Berea
Core, Spraberry Brine and Crude Oil
Slide 22
Dynamic Imbibition Modeling Rectangular grid block with grid
size : 10 x 10 x 3 (Berea) ; z = 9 layers for Spraberry Single
porosity, 2 phase and 3-D Fracture layer between the matrix layers
Inject into the fracture layer Alter matrix capillary pressure only
to match the experimental data zero P c for fracture straight line
for k rw and k ro fracture use k rw and k ro matrix from the
following equations (Berea core):
Slide 23
Match Between Experiment al Data and Numerical Solution Berea
Core Spraberry Core Cumulative water production vs. time Cumulative
oil production vs. time Cumulative water production vs. time
Cumulative oil production vs. time
Slide 24
Capillary Pressure Curves Obtained by Matching Experimental
Data (Berea and Spraberry Cores)
Slide 25
Dimensionless Fracture Capillary Number Lab Units: Field Units:
AmAm w dz AfAf Capillary force ( cos A m ) Viscous force (v w A f )
h
Slide 26
Injection Rate versus Oil-cut
Slide 27
Upscaling of Critical Injection Rate
Slide 28
Conclusions The capillary pressure curve and wettability index
obtained from spontaneous imbibition experiments indicate the
Spraberry cores are weakly water-wet. Effect of pressure is much
less important than the effect of temperature on imbibition rate
and recovery. Performing the imbibition tests at higher temperature
results in faster imbibition rate and higher recovery due to change
in mobility of fluids.
Slide 29
An effective capillary pressure curve can be derived from
dynamic imbibition experiments as a result of matching between
experimental data and numerical solution. Imbibition transfer is
more effective for low injection rates due to lower viscous forces
and longer time to contact the matrix. The capillary pressure curve
obtained from dynamic imbibition experiments is higher that of the
static imbibition experiments due to viscous forces during the
dynamic process. Conclusions (Conted)