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Research Perspectives: Maximizing Oil Recovery by
IOR/EOR
Arne Skauge Managing Director
CIPR – Centre for Integrated Petroleum Research
Uni Research and University of Bergen
The Future of Solutions: Technologies for Increased Oil Recovery (IOR)Monday 30th April, 08:00 – 10:30 AM Monarch Room (24th floor), The Westin Galleria Houston,
Facts about CIPR
CIPR is the Norwegian Centre of Excellence focusing on maximizing oil recovery
CIPR conducts applied research into increased oil recovery and energy efficient utilization of CO2
Key research areas are: Improved Oil Recovery / Enhanced Oil RecoveryReservoir Simulation Geoscience
– 70 researchers (many with extensive industry experience)
– 30 PhD students
– 40 master students
CIPR is a cooperation between the University of Bergen and Uni Research
VisionDevelop new exploration and increased recovery technology to make NCS a leading technology driven petroleum province in 2020.
GoalDevelop new technology to add 7.7 billion bbl o.e.
Maximizing oil recovery for offshore oil and gas fields
Challenges
Identify undrained area
Well distance
Well placement
Logistics
Maximizing oil recovery for offshore oil and gas fields
Challenges Actions
Identify undrained area 4D seismic and EM
Well distance drill cheep/fast new wells
Well placement sidetrack injectors into the oil zone
Logistics minimize the amount of chemicals for EOR
Contributions to closing the production gap
Reservoir descriptionBest reservoir modelReservoir communication
Enhanced oil recovery methodsMove trapped oilSweep improvement
Simulation methodsBetter predictions
Monitoring Find best drilling targets
Time
Oil
Pro
du
cti
on
Ra
te
A
B
Incremental Oil Recovery
Surfactant Polymer Water Oil
• Surfactant• Polymer• Alkaline• Foam
Dynamic Reservoir Characterization
Obtain Vp, Vs and
Understand productioneffects on seismics
Obtain reservoirparameters
Obtain model
Real Time ReservoirManagement
Real Time ReservoirManagement
• Mathematical modelling
• Numerical modelling
• Inverse Problems
• Optimization
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3D & 4D SEISMIC
GEO MODELLING
PRODUCTION DATA
Find best well target
Average 1,68
StatusMechanisms Technology Prognosis Prediction Upscaling
WAG
Foam
Surfactant flooding
Microbial IOR
Low salinity polymers
Proven technology Progress needed Unsolved
GoalMechanisms Technology Prognosis Prediction Upscaling
WAG
Foam
Surfactant flooding
Microbial IOR
High salinity polymers
Some selected Enhanced Oil Recovery technologies
P-39 Production Performance
0
1 000
2 000
3 000
4 000
5 0 00
6 000
jul-96 jan-97 jul-97 jan-98 jul-98 jan-99 jul-99 jan-00 jul-00 jan-01
Q oil
WAG+FAWAGWAG
start FAWAG
Oil
pro
du
ctio
n (
Sm
3/d
)FAWAG – Foam Assisted WAGSnorre field
Ref: Skauge, A., Aarra, M.G., Surguchev, L., Martinsen, H.A., Rasmussen, L., SPE 75157, ”Foam-Assisted WAG: Experience from the Snorre Field”, 2002
Conventional Chemical Methods for Enhanced Oil Recovery
• Surfactants to lower the interfacial tension between the oil and water or change the wettability of the rock
• Water soluble polymers to increase the viscosity of the water
• Polymer gels for blocking or diverting flow
• Combinations of chemicals and methods
International status of EOR
Polymer (Daqing, Dahlia, Marmoul, Captain, ..)(possible on Mariner, Rassey, Grane, etc.)
ASP, SP (Daqing, 20+ pilots)
New processes (10+ pilots)
Daqing Polymer Injection
Project Description:• Over 2000 wells now injecting
polymer at Daqing• Typical slug size is 0.6 PV• Most well patterns are 5-spot• about 30-50% of injected
polymer is produced• maximum produced polymer
conc. is approx. 2/3 of injected
Lessons Learned: • Higher initial water cut results in
lower incremental gains in recovery (see figure to left)
• The total cost of polymer flooding ($6.60/bbl inc. oil) is actually less than for waterflooding ($7.85/bbl inc. oil) due to decreased water production and increased oil production.
• More heterogeneous reservoir: – larger increase in sweep
efficiency– shorter response time to
polymer flooding– strongest influence on
recovery is connectivity of pay zones
• To obtain higher recovery with polymer flooding:– lower producer WHP– stimulate producers– increase polymer
concentration– increase polymer molecular
weight
New trends – hybrid EOR
Example of hybrid EOR methods
WAGFAWAG (Foam Assisted WAG)SAGD (Steam Assisted Gravity Drainage)
Low salinity - surfactantLow salinity - polymersLow tension gas
New combination of EOR methods
Low salinity waterflood may give only modest improved oil recovery for many sandstone reservoirs
Cost of reducing water salinity may be a show stopper
Recent research has made a combined low salinity and surfactant flooding a way of boosting oil recovery and improve the economy of this EOR process
Source:Alagic and Skauge (CIPR): “Change to Low Salinity Brine Injection in Combination with Surfactant Flooding,” presented at 15th European Symposium on Improved Oil Recovery — Paris, France, 27 – 29 April 2009
0
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100
0 1 2 3 4 5 6 7 8 9 10 11 12 13PV injected
Oil R
ecov
ery
[%]
Experimental Data Best Fit LS-S flood on Core B2
Combined low salinity and surfactant injection
LS
LSS
Skauge, A., Kallevik, G., Ghorbani, Z., and Delshad, M., Simulation of Combined Low Salinity Brine and Surfactant Flooding, paper the EAGE IOR Symposium 12th – 14th April 2011 in Cambridge, UK.
Example of game changerPolymer floodingTraditionally polymer is injected for sweep improvement
Old rules of tumbsPoor injectivity (a lot of positive results on injectivity arre now
available)Little effect after extensive waterflooding (new results disprove
this statement)Have to modify the viscosity ratio extensively (new results
disprove this statement)
Additional newsEffect on microscopic displacement (lower Sor)(viscoelastic effects, etc)
0
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60
70
0 1 2 3 4 5 6 7 8 9
Injected Volume (PV)
Oil
Re
co
ve
ry (
% O
OIP
)
E7000
E2000
Water- and polymer flood of viscous oils
Skauge, A., Ormehaug, P:A., Gurholt, T., Vik, B., Bondino, I., and Hamon, G., 2-D Visualisation of Unstable Waterfloodand Polymer Flood for Displacement of Heavy Oil, SPE 154292, paper prepared for presentation at the Eighteenth SPE Improved Oil Recovery Symp. Tulsa, 2012
Skauge, A., Ormehaug, P:A., Gurholt, T., Vik, B., Bondino, I., and Hamon, G., 2-D Visualisation of Unstable Waterfloodand Polymer Flood for Displacement of Heavy Oil, SPE 154292, paper prepared for presentation at the Eighteenth SPE Improved Oil Recovery Symp. Tulsa, 2012
Mohanty et al 2012
Waterflooding at adverse mobility ratio
Red: increased oil saturationLight blue: increased water saturation
Oil mobilization during polymer flood
Skauge, A., Ormehaug, P:A., Gurholt, T., Vik, B., Bondino, I., and Hamon, G., 2-D Visualisation of Unstable Waterfloodand Polymer Flood for Displacement of Heavy Oil, SPE 154292, paper prepared for presentation at the Eighteenth SPE Improved Oil Recovery Symp. Tulsa, 2012
2012
Low salinity polymer
S6-S7:4-weeks aged Berea cores
0
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0 5 10 15 20 25
Volume Injected (PV)
Oil
prod
uctio
n (%
OO
IP)
Low Sal 300 ppm polymer
Source: Behruz Shaker and Arne Skauge, 2012
Low salinity polymer
Prediction for the coming yearsWe will see more advanced flood sequences…
• Polymer - new development and possibilities (Yes)• Low salinity (?)• Classical surfactant flooding (?)
Hybrid EOR – YES
• LSS – LSP – LSASP - LSLTG• Foam-Polymer – Nano stabilized foam- Low Tension Gas –
WAG – Foam Assisted WAG (FAWAG) and more…..
Thank you