The Mechanism of Improved Oil Recovery by …...The Mechanism of Improved Oil Recovery by Sequential...
Transcript of The Mechanism of Improved Oil Recovery by …...The Mechanism of Improved Oil Recovery by Sequential...
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The Mechanism of Improved Oil Recovery by Sequential
Waterflooding
Nina Loahardjo, Xina Xie, Winoto Winoto, Jill Buckley, Norman Morrow
13 January 2010
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Oil Recovery : Waterflooding
Single 5-Spot Well Pattern
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brinecore
Laboratory Measurement of Oil Recovery by Waterflooding
0
20
40
60
80
100
0 2 4 6 8 10 12
Oil
Reco
very
, %O
OIP
Brine Injected, PV
Target for Tertiary Recovery
Oil Recovery by Waterflood
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Further observations at UW that developed from
investigation of low salinity flooding with
re-use of individual reservoir cores
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Cyclic flooding with cleaning, re-aging and change in salinity
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Baselines for assessment of improved oil recovery
No previous study of reproducibility of consecutive floods of recovery of crude oil
had been reported
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Sequential waterfloods of outcrop sandstones and carbonates
• No initial cleaning needed(the notorious problems of cleaning reservoir cores are avoided)
• No change in salinity• No cleaning or re-aging between floods
Can a water flood be reproduced?
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Outcrop Berea Sandstone
• Ta = 75oC• ta = 14 days• Td = 60oC
• WP Crude Oil
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Sequential flooding of sandstone with crude oil at 60oC
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Outcrop Bentheim Sandstone(very low clay content)
• Ta = 75oC• ta = 14 days• Td = 60oC
• WP Crude Oil
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Sequential flooding of Bentheim sandstone (Bth 01) with seawater
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Sequential flooding of Bentheim sandstone (Bth 02) with seawater
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Outcrop Limestone (EdGc)
• Ta = 75oC• ta = 14 days• Td = 60oC
• WP Crude Oil
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Sequential flooding of Limestone with crude oil at 60oC
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Summary of change in Sorfor sequential waterflooding
(Td = 60oC)
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Residual oil for sequential waterflooding for LK reservoir, limestone and sandstone cores at Td = 60oC at 6 PV of seawater injection
Limestone
Bentheim Sandstone
Berea Sandstone (BS)Reservoir
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Confirmation of Reduction in Residual Oil Saturation
by Sequential Waterflooding
Magnetic Resonance Imaging(ConocoPhillips Facility)
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Waterflood – 2D images
Swi = 26%
Sor = 37 %
0 min
8 min
16 min
24 min
320 min
WF1 WF2 WF3Swi = 30%
Sor = 25%
0 min
8 min
16 min
24 min
300 min
Swi = 30%
Sor = 20%
0 min
8 min
16 min
24 min
300 min
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Residual oil for sequential waterflooding for displacement of WP crude oil at 60oC
Limestone
Bentheim Sandstone
Berea Sandstone (BS)Reservoir
BS/MRI/2D
BS/MRI/3D
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Conclusion
Sequential waterfloods for recovery of crude oil without core cleaning and restoration between floods and without change of salinity, usually exhibit large reductions in residual oil.
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Two patents filed by UW:1. Field wide application (disclosure and
provisional patent) 2. Single well testing and diagnostics
(disclosure)
Sequential waterflooding has potential application as a new improved recovery
technique
Explanation of the recovery mechanism?
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The Mechanism
The mechanism should be much less complex than for low salinity flooding because there is no change in brine composition and no cleaning or no re-aging between floods.
Clues!
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When does sequential waterflooding not
give increased oil recovery?
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Recovery of Refined Oil Berea Sandstone
• No Aging • Td = 22oC
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Sequential flooding with refined oil at 22oC
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Observation
Recovery of refined oil from outcrop rock (very strongly water wet conditions) by sequential flooding gives closely reproducible results.
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Recovery of C rude Oil – No Aging –
(no elevation of temperature and minimal time of contact with the crude
oil)
• Td = 22oC
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Sequential flooding of sandstone with crude oil at room temperature
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Recovery of crude oil – No Aging
Conclusion • Aging of the rock with crude oil is
needed for increased recovery by sequential flooding.
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Recovery of refined oil from a mixed-wet Berea core
• Ta = 75oC• ta = 14 days• Td = 60oC• WP Crude Oil /
Refined Oil
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Recovery of refined oil from a mixed-wet Berea core
Preparation• The core is aged at Swi with crude oil • The crude oil is displaced by an intermediate solvent
(to avoid destabilization of asphaltenes)
• The solvent is displaced by mineral oil to leave an adsorbed oil film
- a mixed-wet condition referred to as MXW-F
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Preparation of MXW-F cores
S220Decalin
MXW MXW-F
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Recovery of refined oil by sequential flooding of MXW-F Berea
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Oil recovery from MXW-F core
Observations • Characteristically high recovery for the first flood
(nearly 80% OOIP). • There was no change in recovery from the first to the
second flood.Conclusions• For MXW-F cores, the adsorbed film in the presence
of mineral oil is more robust with respect to stability of
wetting. • In addition to adsorption, the crude oil brine interface
and/or bulk crude oil is needed.
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Comparison of saturation profiles at breakthrough & final distribution (Sor)
by MRI imaging
• Ta = 75oC• ta = 14 days• Td = 60oC• WP Crude Oil
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Final oil distribution
Breakthrough oil distribution
R1/C1
PVI = 0.48 4.7
Core
1D NMR Profiles of oil distribution
R1/C2
PVI = 0.48 4.4
R1/C3
PVI = 0.48 4.4
R1/C4
PVI = 0.48 4.4
1D profiles of oil distribution at water breakthrough and at residual oil saturation
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C hange in MRI saturation profile and oil recovered after breakthrough
Observation• Increase in proportion of oil recovered
after breakthrough for consecutive floods implies that there is a change in wettability* after exposure of the core to increased water saturation
* the crude oil/brine/rock interactions that determine oil recovery
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Spontaneous imbibition before and after aging a core at
high water saturation
• Ta = 75oC• ta = 65 days• Ti = 75oC• Td = 80oC• WP Crude Oil
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1 10 100 1000 10000 1000000
10
20
30
40
50
60
70
80
90
100
=ϕD 2
co w
k• tt
Lµ µ
=ϕD 2
co w
k• tt
Lµ µ
VSWW
Rim
(% O
OIP
)
Dimensionless time,
A-95 crude oil/PB brineS
wi=23.0 +/- 1%
Ta=75 °C for 65 days
Tm=75 °C
TD=80 °C (Sor)
Effect of aging at Sor on subsequent spontaneous imbibition of brine into Berea sandstone
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Spontaneous imbibition before and after aging a core at high water saturation
• Increase in water wetness after aging at Sor and elevated temperature
• After increase in water saturation by spontaneous imbibition and aging at elevated temperature, a subsequently measured imbibition curve showed increased water wetness as indicated by:– decreased induction time for onset of imbibition, – higher rate, – higher recovery
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These and numerous other observations indicate that:
• Wettability is not a fixed crude oil/brine/rock property determined solely by initial aging conditions. Increase in water saturation results in increased water wetness.
• Wettability and direction of wettability change depend primarily on the direction of change of water saturation.
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• The wettability at the onset of a waterflood is not regained by re-flooding the core with crude oil. Each waterflood affects the outcome of a subsequent waterflood.
• Increase in recovery of crude oil by sequential water flooding results from a favorable form of increase in wettability to water that arises from increase in water saturation during each waterflood. The change is only partially reversed by decreasing the water saturation by displacement with crude oil.
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Single-Well Tests of Sequential Floods
Calculations are based on a simple piston-like displacement model
φ =20.9%, 30 ft reservoir oil-zone thickness
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Increased Oil Recovery by Oil Injection Followed by Water Injection
• Sor reduction taken from laboratory data :
Bth 01 3D MRIWF1 50 36WF2 37 29WF3 20 24
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Reservoir at residual oil saturation after waterflood (WF1)
SOR (WF1)=36.2%
target zone radius = 45 ft
Day 00 10 20 30 40 50 ft
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Injection of oil into the target zone
SOR (WF1)=36.2%
target zone radius = 45 ft
SOR (WF1)=36.2%
oil injected = 100 bbl
Day 1
SO=64.9%
0 10 20 30 40 50 ft
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START WATER INJECTION
SOR (WF1)=36.2%
oil bank minimum radial length= 4.5 ft
oil bank volume = 406 bbl
Displacement of injected oil by injection of brine (WF2)
inner radial distance
oil bank radial length
Day 1Day 2
Radial length of oil reaches minimum before growing upon more injection of brine
0 10 20 30 40 50 ft
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SOR (WF1)=36.2%
C ontinuation of oil bank displacement by injection of brine (WF2)
oil bank radial length= 5.9 ft oil bank volume = 1,149 bbl
SO=64.9%
SOR (WF2)=28.8%
Day 2Day 3Day 4Day 5Day 60 10 20 30 40 50 ft
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The well is put on production and the oil bank grows in volume and radial length
SOR (WF1)=36.2%
Day 6Day 8Day 9Day 100 10 20 30 40 50 ft
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SOR (WF1)=36.2%SOR (WF2)=28.8%SOR (WF3)=24.0%
Day 10Day 11Day 12Day 13Day 14
The well is put on production and the oil bank grows in volume and radial length
0 10 20 30 40 50 ft
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Single Well Field Test
4,000 bbl oil in 62 days(as high as 15,000 bbl optimistically)
900 bbl oil in 14 days(as high as 3200 bbl optimistically)
2,000 bbl brine
100 bbl oil
10,000 bbl brine 100 bbl
oil
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Many possibilities exist for other approaches to improved recovery by
injection of small volumes of oil• Example 1 : Inject multiple oil banks• Example 2 : Improve recovery of sequential
floods by displacing injected oil with low salinity brine.
• Example 3 : Pre-injection of oil will convert a tertiary mode low salinity flood into a much more effective secondary mode low salinity waterflood.
• Example 4 : Pre-inject low salinity brine
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Discussions were held with six major companies in Oct/Nov 2009
to suggest that they test sequential flooding in their production research
laboratories and/or perform field tests.
(Response was encouraging)
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Field test : advantages/diagnostics
• Low cost: Injected brine and oil are directly available: Required oil volume is small
• Single well test gives direct volumetric measure of oil production
• Tracers added to the injected oil and brine will allow monitoring of mixing of injected oil and brine with reservoir oil and brine
• Oil/brine production ratios will indicate heterogeneity and viscous fingering
• Flow reversal will tend to counteract rock heterogeneities and phase distribution effects
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Further Laboratory Work
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1. Core Floods and Imbibition Tests
• test different crude oils and rocks including Minnelusa, Tensleep, Cottonwood Creek, WP etc
• tests with longer cores• monitor wettability by imbibition tests between
sequential waterfloods• re-age the core at initial water saturation
between each sequential flood (to see if the sequential flooding effect is diminished)
• run additional MRI corefloods for sandstone and limestone cores
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2. Pore scale mechanism – Micro X-ray C T –(Joint Wettability Project with Australian National Univ.)
• Change in pore-scale distribution by of initial brine and residual oil before and after each sequential waterflood:
– 1st tests are planned for Bentheim sandstone (low clay content will give excellent density contrast for discrimination between quartz, oil, and brine at the pore scale – 2 µ resolution)
– Changes with low salinity flooding for Tensleepand Minnelusa are also under investigation
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Conclusions
• Each flood causes change in wetting properties; water wetness increases with water saturation
• Sequential waterflooding without change in salinity and without cleaning or re-aging between cycles showed reductions in residual oil saturation
• NMR imaging confirmed the effect of sequential waterflooding
• Single-well field testing of sequential waterflooding is justified
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Manuscripts in preparation
• Detailed Account of Mechanism : 11th Int. Symp. on Reservoir Wettability, Sept., Calgary, Alberta
• Additional results (since Abu Dhabi 2008) and field test approach : SPE 2010 (Oct) Annual Meeting,
• MRI results (Joint with ConocoPhillips) : SCA Sept 2010
Note : draft copies should be available for the next EORI Meeting
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Acknowledgements
• BP, Total, StatoilHydro, ARAMCO,
ConocoPhillips, Chevron
• The Wold Chair
• Charlie Carlisle
• Petrophysic and Surface Chemistry Group
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Thank You !