Chemical Enhanced Oil Recovery Malcolm J. Pitts Surtek, Inc. · 2020. 6. 16. · Recovery Summary....
Transcript of Chemical Enhanced Oil Recovery Malcolm J. Pitts Surtek, Inc. · 2020. 6. 16. · Recovery Summary....
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SURTEK
Chemical Enhanced Oil Recovery
Malcolm J. Pitts Surtek, Inc.
SURTEK
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SURTEK
Oil Bank
Waterflood Residual OilA
SP
Poly
mer
Wat
er
Chemical Flood Mechanism
Injection Production
Ultimate Residual Oil
Chemical Flood is Not like a waterfloodChemical Flood effects only reservoir contacted by chemicals
• Fluid is Injected at an Injection Well• Injected Fluid Moves through an Oil Reservoir• Mobilized Oil Produced at a Production Well
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SURTEK
o
poVIAD B
VSEEENp •=
Oil Recovery Equation
Capillary Number Mechanism –Pore to PoreDisplacement EfficiencyHow well does the injected fluid move oil?
Mobility Control Mechanism -Volumetric Displacement EfficiencyOil Recovery
Stock Tank Oil Saturation
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SURTEK
• application objectives• recover 15 to 30% OOIP as incremental oil• cost of incremental oil is less than $20.00/bbl• rate of return 50% or greater
• two primary mechanisms• a mobility control mechanism • a capillary number mechanism
Chemical Floods
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SURTEK
σLP
ForcesSurfaceForcesViscousNca
/Δ==
Capillary Number Mechanism
Improves ED
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SURTEK
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SURTEK
0.0 0.5 1.0 1.5 2.0 2.5Alkali Concentration (wt%)
1E-3
1E-2
1E-1
1E+0
1E+1
Inte
rfac
ial T
ensi
on (m
N/m
)
Na2CO
3+ Surfactant
NaOH + Surfactant
42 API
22 API
Alkali-Surfactant IFT Reduction
0.0 0.5 1.0 1.5 2.0 2.5Alkali Concentration (wt%)
1E-3
1E-2
1E-1
1E+0
1E+1
Inte
rfac
ial T
ensi
on (m
N/m
)
Na2CO
3
NaOH
42 API
22 API
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SURTEK
Interfacial Tension Criteria
interfacial tension reduction alone does not result in good oil recovery
150 oF Interfacial TensionInjected Solution (mN/m)- ASP Solution #1 <0.001 - ASP Solution #2 <0.001- ASP Solution #3 <0.001- ASP Solution #4 0.001
0.0 1.0 2.0 3.0 4.0 5.0Cumulative Produced Fluids (PV)
0
10
20
30
40
50
60
70
Cum
ulat
ive
Oil
Rec
over
y (%
OO
IP)
Primary and Waterflood Chemical Flood
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SURTEK
Alkali and Surfactant• alkali
• alters rock wettability• reacts with oil to form surfactants• adjusts pH and salinity• alters rock chemistry, reducing adsorption• acts as a mild biocide• stabilizes polyacrylamide to H2 S catalyzed
oxidative degradation• surfactant
• reduces oil-water interfacial tension• alkali plus surfactant
• synergistic interfacial tension reduction
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SURTEK
Alkaline Agents
Increase solution pH > 7
Most common alkalis used in chemical floods are:
• soda ash (Na2 CO3 )
• caustic soda (NaOH)
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SURTEK
Surfactant
Surfactant (surface active agent)
C7 – C10
C4 – C5
CH3
H3C
H3C SO-
3 Na+
Hydrophobic
Hydrophillic
AnionicCationicNon-ionicZwitterionic - Amphoteric
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SURTEK
oiloil
waterwater
kk
MobilityPhaseDisplacedMobilityPhaseDisplacingM
μμ
//
==
Mobility Control Mechanism
Improves EVI and EA
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SURTEK
Polymers
Macromolecules composed of repetitive units - monomers
Most common CEOR polymers are:
• hydrolyzed polyacrylamide (HPAM)
• xanthan gum (biopolymer)•Most important CEOR property
• changing mobility of injected fluid
• increase viscosity
• reduce effective water permeability
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SURTEK
Oil Displacement in 5-spotWaterflood, break through in 1 hour 19 minutes
Polymer flood, break through at 2 hours and 4 minutes, better sweep
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SURTEK
Alkali,Surfactant, and Polymer• Capillary Number Mechanism
• alkali• surfactant
• improve oil removal from pores
• Mobility Control Mechanism• polymer
• improve contact efficiency• improve displacement of oil to well
• Combining Mechanisms• synergistic oil recovery
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SURTEK
Wilmington Crude Oil
Waterflooded to Sorw = 0.40 Vp
Flooded with 1 pore volume low IFT slug
Flushed with 2 pore volumes of water
Recovered 0.05 pore volume incremental oil
Sof = 0.352 “
dia.
2 foot length©
SURTEK
Capillary Number Mechanism
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SURTEK
Wilmington Crude OilWaterflooded to Sorw = 0.40 Vp
Sof = 0.35
Sof = 0.36
Flooded with 1 pore volume polymer = oil viscosityFlushed with 2 pore volume of water
Recovered 0.04 pore volume incremental oil
©
SURTEK
Mobility Control Mechanism
Capillary Number Mechanism
2 foot length
2 “
dia.
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SURTEK
Flooded with 1 pore volume ASP Solution Viscosity of ASP Solution = oil viscosity
Recovered 0.37 pore volume incremental oil
Sof = 0.03
Sof = 0.36
Sof = 0.35
©
SURTEK
Capillary Number Mechanism
Mobility Control Mechanism
Combined Capillary Number and Mobility Control Mechanisms
2 foot length
2 “
dia.
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SURTEK
0.0 0.5 1.0 1.5 2.0 2.5 3.0Normalized Cumulative Produced Fluids (PV / PV Waterflood)
0.0
0.5
1.0
1.5
2.0
N
orm
aliz
ed C
umul
ativ
e O
il R
ecov
ery
(%O
OIP
Rec
over
y / %
OO
IP W
ater
flood
)
Alkaline-Surfactant-Polymer FloodWaterflood
Berea
J Sand
Muddy
Sand Type Effect on Recovery
reservoir rock is critical for a successful design
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SURTEK
Tanner Field
Mellott Ranch
Cambridge
Timing of Floods• Cambridge
secondary flood• Tanner
waterflood to40% oil cut
• Mellott Ranch35 yearswaterflood to5% oil cut
Alkaline-Surfactant-Polymer Floods
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SURTEK
Secondary Alkaline-Surfactant-Polymer Flood Net Pay Isopach
Alkaline- Surfactant- Polymer Flood InjectionWell
Cambridge FieldASP area = 5,684 MBBL PV
Mobility Ratio = 2.2 to 5.8
Permeability = 845 md
Oil API Gravity = 20o
Oil Viscosity = 31 cpAlkaline-Surfactant-Polymer flooding beginning 1993
SPE Res. Eng., Dec. 2000
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SURTEK
Cambridge Alkaline-Surfactant-Polymer Flood Production
1989 1993 1997 2001 2005
1,000
10,000
100,000O
il (b
bl/m
onth
)
1
10
100
% O
il C
ut
ActualActualSimulatedOil Cut
Oil Production
HistoryMatchPrimary
ForecastSecondaryASP Flood
Primary
Alkaline-Surfactant-Polymer Flood
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SURTEK
Cambridge Federal 23-28
1989
1994
1999
2004
2009
100
1,000
10,000
100,000
Oil
(bbl
/mon
th) -
Wat
er (b
bl/m
onth
)
0.1
1.0
10.0
100.0
% O
il C
ut
Oil Cut
Oil
Water
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SURTEK
Cambridge Alkaline-Surfactant-Polymer Flood Recovery Summary
Ultimate Oil Recovery 73.2 %OOIPPrimary and Waterflood 39.8 %OOIP
ASP Incremental Recovery 33.4 %OOIP
Cost per Incremental Barrel 2.95 $/bblcost includes chemicals and plant
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SURTEK
Cambridge Comparison Alkaline-Surfactant-Polymer Flood
0.00 0.05 0.10 0.15 0.20 0.25 0.30 0.35 0.40 0.45 0.50Cumulative Oil after Injection Begins
Cumulative Waterflood or ASP Oil (Vp)
1
10
100%
Oil
Cut
Field ComparisonsCamridgeMellott Ranch ASP floodAverage Waterflood
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SURTEK
Alkaline- Surfactant- Polymer Flood InjectionWell
Mid-Waterflood Alkaline-Surfactant-Polymer Flood Net Pay Isopach
SPE 100004
Tanner FieldASP area = 2,528 MBBL PV
Mobility Ratio = 3.2
Permeability = 200 md
Temperature 175oF
Oil API Gravity = 21o
Oil Viscosity = 11 cp
Waterflood beginning November 1997
Alkaline-Surfactant-Polymer flooding beginning March 2000
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SURTEK
Tanner, Wyoming Alkaline-Surfactant-Polymer Flood
1991 1993 1995 1997 1999 2001 2003 2005 2007 20091
10
100
% O
il C
ut
1,000
10,000
100,000
Mon
thly
Oil
Prod
uctio
n (b
bls)
Primary
Waterflood
Alkaline-Surfactant-PolymerFlood
Oil Cut
Oil Production
CalculatedContinuedWaterfloodOil Cut
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SURTEK
Tanner Alkaline-Surfactant-Polymer Flood Recovery Summary
Ultimate Oil Recovery 65.0 %OOIP
Primary and Waterflood 48.0 %OOIPto 3% oil cut
ASP Incremental Recovery 17.0 %OOIP
Cost per Incremental Barrel $4.49 (estimated)Includes Chemical and Facilities
Primary and Waterflood 31.3 %OOIPto 3/2000 – 40% oil cut
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SURTEK
Tanner Alkaline-Surfactant-Polymer Flood Production Compared to Eight Minnelusa Waterfloods
Tanner
0.00 0.05 0.10 0.15 0.20 0.25 0.30 0.35 0.40 0.45 0.50Cumulative Oil Produced After Injection Begins (PV)
1
10
100
% O
il C
ut
Field ComparisonsCamridgeTotal Tanner FieldTanner 24-30Tanner 22-31Tanner Calculated WaterfloodAverage Waterflood
arrows incicate start of ASP for TannerMay 2000
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SURTEK
Alkaline- Surfactant- Polymer Flood InjectionWells
Tertiary Alkaline-Surfactant-Polymer Flood Net Pay Isopach
`H
Water Injection Well
Mellott Ranch FieldASP area = 12,200 MBBL PV
Mobility Ratio = 7.6
Permeability = 640 md
Temperature 133oF
Oil API Gravity = 21o
Oil Viscosity = 23 cp
Waterflood beginning December 1965
Alkaline- Surfactant- Polymer flooding beginning August 2000
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SURTEK
Mellott Ranch Northeast Sand, Northern Wells 34-02, 41-11, and 11-12H Producing
21-11 and 32-1 Injecting
1961 1966 1971 1976 1981 1986 1991 1996 2001 20061.0
10.0
100.0
% O
il C
ut
1,000
10,000
100,000
Mon
thly
Oil
and
Wat
er P
rodu
ctio
n (b
bls)
Oil CutOilWater Injection
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SURTEK
Mellott Ranch Northeast Sand, Northern Wells 34-02, 41-11, and 11-12H Producing
21-11 and 32-1 Injecting
1991 1995 1999 2003 2007 20111.0
10.0
100.0
% O
il C
ut
1,000
10,000
100,000
Mon
thly
Oil
and
Wat
er P
rodu
ctio
n (b
bls)
Oil CutOilWater Injection
ASP Injection August 2000
Polymer DriveJune 2004
WaterMay 2006
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SURTEK
Mellott Ranch Northeast Sand Waterflood Comparison Alkaline-Surfactant-Polymer Flood
0.00 0.05 0.10 0.15 0.20 0.25 0.30 0.35 0.40 0.45 0.50Cumulative Oil Produced After Injection Begins (PV)
1
10
100
% O
il C
ut
Field ComparisonsCamridgeMellott Ranch ASP floodAverage Waterflood
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SURTEK
Secondary Alkaline-Polymer Flood Net Pay Isopach
Thompson Creek FieldAP area = 26,000 MBBL PV
Mobility Ratio = 13.6
Permeability = 1,400 md
Temperature 88oF
Oil API Gravity = 19o
Oil Viscosity = 300 - 515cp
Waterflood beginning July 2002
Alkaline- Polymer flooding beginning May 2004
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SURTEK
10
100
1000
STB
/day
Jul-87 Jul-92 Jul-97 Jul-02 Jul-07 Jul-12 Jul-17 Jul-22
020406080
100
Oil
Cut
%
Thompson Cr. – Wyoming USABegin AP Injection
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SURTEK
Thompson Cr. – Wyoming
Additional Recovery
Less Injection
0.0 0.5 1.0 1.5 2.0 2.5Cumulative Injection, PV
0
1,000
2,000
3,000
4,000
5,000
6,000
Cum
ulat
ive
Oil,
MB
BL
Alkaline-Polymer ForecastWaterflood ForecastActual
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SURTEK
Alkaline-Polymer FloodEtzikomAP area = 21,500 MBBL PV
Mobility Ratio = 17.2
Permeability = 1000 md
Temperature 86oF
Oil API Gravity = 19o
Oil Viscosity = 100 cp
Waterflood beginning 1971
Alkaline- Polymer flooding beginning December 2000
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SURTEK1967 1972 1977 1982 1987 1992 1997 2002 2007 2012
0
10
20
30
% O
il C
ut
0
10,000
20,000
30,000
Mon
thly
Oil
and
Wat
er P
rodu
ctio
n (b
bls)
Field Oil CutField Oil Rate
APDec 2000
Polymer DriveMarch 2003
WaterMay 2005
Chemical Flood oil productionmatches historical maximum rate
Oil CutIncrease2.5 to 17.0%
Oil Rate Increase10,200 bbl/m to29,100 bbl/m
Alkaline-Polymer Flood Etzikom C Pool 22,000,000 bbl Full Field
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SURTEKSURTEK1967 1972 1977 1982 1987 1992 1997 2002 2007 2012
0.1
1.0
10.0
100.0
% O
il C
ut
100
1,000
10,000
100,000
Mon
thly
Oil
and
Wat
er P
rodu
ctio
n (b
bls)
Oil CutOilWater Production
Etzikom Alkaline-Polymer FloodWell 03-24 of C Pool
33 years primary and waterflood
7.5 years alkali-polymer flood
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SURTEKSURTEK
0 50,000 100,000 150,000 200,000 250,000 300,000Cumulative Oil (bbls)
0.1
1.0
10.0
100.0
% O
il C
ut
100
1,000
10,000
100,000
Mon
thly
Oil
and
Wat
er P
rodu
ctio
n (b
bls)
Oil CutOilWater Production
Etzikom Alkaline-Polymer FloodWell 03-24 of C Pool
33 years primary and waterflood140,000 bbls
7.5 years alkali-polymer flood140,000 bbls additional
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SURTEK
Alkaline-Surfactant-Polymer FloodWarnerASP area = 50,000 MBBL PV
Mobility Ratio = 10.9 – 12.4
Permeability = 2100 md
Temperature 95oF
Oil API Gravity = 19o
Oil Viscosity = 58 cp
Polymer Flood beginning 19672 injection wells
Water beginning 1972
Alkaline-Surfactant-Polymer flooding beginning May 2006
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SURTEK
1963 1968 1973 1978 1983 1988 1993 1998 2003 2008 2013
0
2
4
6
8
10
% O
il C
ut
0
20,000
40,000
60,000
80,000
100,000
Mon
thly
Oil
Prod
uctio
n (b
bl)
Oil CutOil Rate
ASP InjectionMay 2006
Oil Rate Increasedfrom 9,000 bbl/m to49,600 bbl/m
Oil Cut Increasedfrom 1.7 to 8.4%
Alkaline-Surfactant-Polymer Flood Warner 50,000,000 bbl Full Field
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SURTEK
What Makes a Successful Flood?
• reservoir engineering and geology• laboratory evaluation• numerical simulation• facilities design• careful field operations• monitoring flood performance
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SURTEK
Thank You!