Laboratory Program - University of Wyoming - tab designer wf... · Laboratory Program ... Yousef et...
Transcript of Laboratory Program - University of Wyoming - tab designer wf... · Laboratory Program ... Yousef et...
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
Laboratory Program (Modified Injection Brines for Waterfloods)
Geoffrey Thyne
Haifeng Jiang
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
Improved
Recovery
Screen to
assess
potential for
WY
Reservoir-
specific Lab
tests
Field
scale
models
Field
Testing
Identify
Promising
Technique
for WF
EORI Lab
Program
Components
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
EORI Lab Program Project Basis
Procedure Project Time
Standard waterflood 10-12 experiments 3-4 months
CO2-WAG waterflood 10-12 experiments 4-5 months
Development of new capability/equipment 9-12 months
Regular Maintenance 1 month/year
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
Modified Injection Brines Methodologies being investigated
• Low Salinity Waterflood – Looking for potential reservoirs
in Wyoming based on research and field experiences
• Designer WF– Experimental Evaluation of new
technique for Wyoming
• Advantages – Both are inexpensive and easy to
implement.
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
The fundamental objective is to change wettability in
the reservoir to increase oil recovery by changing the
chemistry of the injected water.
Low salinity appears to have multiple mechanisms
that include wettability alteration, demonstrated field-
scale success and failure.
Designer Waterfloods appears to be wettability
alteration only.
Waterfloods (Modifying Injection Brine)
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
SPE 143550
Yousef et al. 2011 -Saudi Aramco
Carbonate reservoir (calcite and
dolomite mineralogy)
NMR shows change in
Wettability with change in salinity
Low Salinity Waterflooding - Carbonates
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
Low Salinity Screening
• Apply experimental and literature results to develop screening. – Lab experiments and field data show inverse relationship between
temperature of flooding and incremental recovery.
– Lab experiments show no incremental recovery without fines migration potential.
• Cumulative Oil, Salinity, Temperature, Rock Composition, are screening criteria for Wyoming.
.
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
Wyoming – Low Salinity Screen Top 20
Field Name Reservoir T (°C) TDS (ppm)
Cumulative
Production Oil
(bbls)
Basin
HALVERSON MINNEKAHTA 74 195,919 16,731,354 E. FLANK PBR
DONKEY CREEK MINNEKAHTA 68 194,509 16,810,691 E. FLANK PBR
BEAVER CREEK PHOSPHORIA 96 104,264 59,197,373 SW WRB
POISON SPIDER WEST CODY 88 99,833 12,230,606 SE WRB
BIRCH CREEK NUGGET 85 99,108 90,470,790 GREEN RIVER
TIP TOP NUGGET 84 88,557 8,753,207 GREEN RIVER
HOGSBACK NUGGET 90 84,902 8,927,619 GREEN RIVER
SAGE CREEK MADISON 40 81,191 13,623,968 NE FLANK BIGHORN
TIP TOP PHOSPHORIA 103 71,007 8,753,207 GREEN RIVER
WORLAND EMBAR 88 68,305 19,492,765 SE BIGHORN
PATRICK DRAW FOX HILLS 45 55,928 10,500,764 GREEN RIVER
GREEN RIVER BEND FRONTIER 68 55,095 13,871,835 GREEN RIVER
LITTLE BUFFALO BASIN CURTIS 43 53,499 137,106,832 WESTERN BIGHORN
BRADY NUGGET 98 50,000 70,358,174 GREEN RIVER
BEAVER CREEK MESAVERDE-2 47 48,422 59,197,373 SW WIND RIVER
BRADY WEBER 115 43,719 70,358,174 GREEN RIVER
WORLAND PHOSPHORIA 87 42,999 19,492,765 SE BIGHORN
OREGON BASIN CHUGWATER 40 41,503 471,127,847 W. FLANK BIGHORN
GRASS CREEK CHUGWATER 43 35,420 212,370,226 SW BIG HORN
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
Emerging Technique – Designer Waterfloods
• Change in wettability (more water-wet) by changing
injected water chemistry. – ‘We're at the beginning here. It's an emerging technology. It's very new. We at
Shell think it's very exciting'.
– Advanced Ion Management (ExxonMobil), Smart WaterFlood (Saudi Aramco),
Designer Water (Shell), Smart Water (Stavanger), BP, Total, Statoil.
– Change in inorganic water chemistry to alter wetting e.g. addition of sulfate,
phosphate and borate ions make carbonate surfaces more water-wet.
• To date experimental work has focused on carbonate
reservoir rock.
• Addition of SO42-, PO4
2- and B(OH)4- has produced
incremental oil in experiments using chalk, limestone
and dolomite.
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
Proposed Mechanism for Altering Carbonate Wettability
+ Carbonate Surface
+
S
O-
O
O-
O
O-
O
Oil
C
P
O-
O
O-
O
B
OH
OH
O-
OH
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
Proposed Mechanism for Altering Carbonate Wettability
+ Carbonate Surface
+
S
O-
O
O-
O O-
O
Oil
C
P
O-
O-
O-
O B
OH
OH
O-
OH
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
SPE 142668
Gupta et al. 2011 – ExxonMobil
Limestone and Dolomite cores
5-9% increment with sulfate
15% with Borate
21% with Phosphate
Designer Waterfloods
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
Screen potential of technique for Wyoming Modified Injection Brine for Carbonates
Are there reservoirs that could benefit?
Prod Zone Name
Sum of Oil
Cum
Sum of Gas
Cum
Sum of Wtr
Cum
BBLS MCF BBLS
MADISON 477,789,462 6,029,426,158 6,591,240,789
EMBAR 344,900,918 172,251,426 3,429,183,519
PHOSPHORIA 259,456,919 332,502,221 1,731,066,310
NIOBRARA 13,598,344 10,637,033 5,791,752
10% OOIP Increment = 100 Million Barrels
Wyoming Carbonate Reservoirs - Cumulative Production
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
• DWF Screening (focus on Madison fields)
– What is dominant salinity?
– What is dominant temperature?
– Are fields currently below saturation
with gypsum and anhydrite?
Screening and Experimental Design
TDS
Frequency
21000180001500012000900060003000
80
70
60
50
40
30
20
10
0
Histogram of Madison produced water TDS
10 20 30 40 50 60 70 80 90 100 1100
5000
1e4
15000
2e4
25000
Temperature (C)
Dis
solv
ed s
olid
s (m
g/k
g)
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Screen shows that
low TDS (≤ 5000
ppm) and low T
(≤50°C) describe
conditions for most
reservoirs
0 1000 2000 3000 4000 5000.01
.1
1
Dissolved solids (mg/kg)
Anhydrite
(Q
/K)
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E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
• Laboratory program
– Standard core flood methodology already developed for low salinity
– Evaluate performance in dolomite with WY brines and oils
– Determine effects of adding SO4 below limit of gypsum/anhydrite saturation
DWF Program for in Carbonates
1000 2000 3000 4000 5000 6000 7000 8000
.3
.4
.5
.6
.8
1
SO4-- in fluid (mg/kg)
Satu
ration,
som
e m
inera
ls (
Q/K
)
Anhydrite
Gypsum
Initial Synthetic Brine
Average of low TDS Madison Reservoirs
Sulfate Addition to Brine
Na K calc Ca Mg HCO3 SO4 Cl TDS
465 51 421 120 702 1242 498 3499
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
EORI Lab Program
DWF Preliminary Evaluation
Procedure Project Time
Standard waterflood 10-12 experiments 3-4 months
Dolomite core + LSU Oil + Synthetic Brine
Baseline single phase (2 cores) 2 experiments
Sulfate Enrichment 10 experiments
(base solution plus 2 modifications with 3000 and 6000 ppm SO4)
Evaluate incremental recovery and potential formation damage
E N H A N C E D O I L R E C O V E R Y I N S T I T U T E
Moving MIB Waterfloods Forward
• Continue to test techniques for Wyoming reservoirs.
• Build Strategic Relationships with Producers.
• Provide producers with reservoir specific test data and
projected performance.
• Provide incentives for producers to implement field
demonstration.