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![Page 1: Reservoir Management Under Water Injection A Worldwide Perspective Dr. William M. Cobb Dallas, Texas 2 nd National Meeting on Secondary and Assisted Oil.](https://reader036.fdocuments.us/reader036/viewer/2022081514/5517afe55503460e6e8b61dd/html5/thumbnails/1.jpg)
Reservoir ManagementReservoir ManagementUnder Water InjectionUnder Water Injection
A Worldwide PerspectiveA Worldwide Perspective
Dr. William M. Cobb
Dallas, Texas
2nd National Meeting on Secondary and Assisted Oil Recovery
September 8–9, 2005
Malargue, Argentina
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Current Oil Production in South America (1000 B/D)
• Argentina 718• Brazil 1538• Colombia 514• Ecuador 533• Mexico 3252• Venezuela 2640• Total 9150
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ArgentinaMonthly Oil Rate vs Time
0
100
200
300
400
500
600
700
800
900
1,000
1,000 BO
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ArgentinaYear 2004 Production
BOPD % of Total
Primary Production
442,000 63.2
Secondary Production
257,000 36.8
Total 699,000 100.0
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ArgentinaMonthly Oil Rate vs Time
0
100
200
300
400
500
600
700
800
9001,000 BO
Primary Production
Secondary Production
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ArgentinaPercent Primary & Secondary Production
0
10
20
30
40
50
60
70
80
90
1994 1996 1998 2000 2002 2004 2006
Primary
Secondary
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.
ArgentinaPrinciple Productive Areas
Noroeste
Cuyana
Neuquina
Gulfo San Jorge
Austral
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ArgentinaPrinciple Production Areas
Total BOPD
% of
Country Total
Austral 47,000 6.7
Cuyana 41,000 5.9
Gulfo San Jorge 284,000 40.6
Neuquina 310,000 44.4
Noroeste 17,000 2.4
699,000 100.0
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Argentina Year 2004 Production
BOPD Primary, % Secondary, %
Austral 47,000 86.6 13.4
Cuyana 41,000 61.7 38.3
Gulfo San Jorge 284,000 60.6 39.4
Neuquina 310,000 60.5 39.5
Noroeste 17,000 100.0 0.0
Total 699,000
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Argentina% of Total Secondary
0.0%
10.0%
20.0%
30.0%
40.0%
50.0%
60.0%
70.0%
Nequina
Gulfo San Jorge
Cuyana
Austral
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Argentina Oil and Injection Well Count vs Time
0
5,000
10,000
15,000
20,000
25,000
2000 2001 2002 2003 2004 2005 2006
Producing Wells
Injection Wells
Total Wells
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Argentina Injection Well Count and Average Daily Injection per Well
0
500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
4,500
5,000
Injection Wells
BWP Day/Well
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ArgentinaWell Distribution on 1/1/05
Producing
% of Total Injectors
% of Total
P/I Ratio
Austral 289 1.7 40 0.8 7.2
Cuyana 938 5.5 246 4.8 3.8
Gulfo San Jorge 11,005 64.2 2,740 53.6 4.0
Neuquina 4,852 28.3 2,086 40.8 2.3
Noroeste 57 0.3 0 0.0 -
Total 17,141 100.0 5,112 100.0 3.4
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Daily NYMEX Oil Price
0
10
20
30
40
50
60
70
80
0
5
10
15
20
Oil PriceOil Price
Gas PriceGas Price
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Common Denominators for Common Denominators for Management of Waterfloods on Management of Waterfloods on
a Worldwide Basisa Worldwide Basis
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Why Inject Water?A. Maintain Reservoir Pressure –
Pressure Maintenance
B. Increase Reservoir Pressure – Waterflooding
C. Supplement Natural Water Influx
But . . .A, B & C are Displacement Processes and the Goal is to Displace Oil to a Production Well
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Pressure Depletion Stops
Volumetric Sweep
Net Pay Cutoffs
Decline Curve Analysis
WOR Analysis
Waterflood Quarterback
Keep the Ax Sharp
Worldwide Reminders When Managing Waterflood Activities
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What are the Key Factors that Drive the Outcome of a Water Injection Project?
Np = Cumulative Waterflood Recovery, BBL.
N = Oil in Place at Start of Injection, BBL.
EA = Areal Sweep Efficiency, Fraction
EV = Vertical Sweep Efficiency, Fraction
ED = Displacement Efficiency, Fraction
Np ≈ N*EA*EV*ED
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Waterflood Recovery Factor
EA = f (Mobility Ratio, Pattern, Directional Permeability, Pressure Distribution, Cumulative Injection & Operations)
EV = f (Rock Property variation between different flow units)
EVOL = Volumetric Sweep of the Reservoir by Injected Water
ED = f (Primary Depletion, Krw & Kro, μo & μw)
RF N
Np DVA E
E
EE
VOL
**RF
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Traditional Waterflood Volumetric Sweep Efficiency Calculation
Uses Net Cumulative Water Injected (Wi-Wp) Does not Account for Injection losses out of
zone Does not Account for Natural Water Influx
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Compute Volumetric Sweep Based on Oil Production Data
Oil in place at start of waterflooding = Produced oil since the start of injection + Oil currently in reservoir
Where:Oil in place at start of waterflood =
Produced oil since the start of injection =
Oil currently in reservoir = Oil in water bank + oil in oil bank
Oil in water bank =
Oil in oil bank =
, STBOp o
o
V S
B
,STBOpN
(1.0 ),STBOp vw w
o
V E S
B
(1.0 )(1.0 ),STBOp vw wc
o
V E S
B
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1.0p oo wc
pvw
w wc
N BS S
VE
S S
Volumetric Sweep Based on Oil Production Data
SPE-38902
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Example
Waterflood Statistics
Conditions at Start of Waterflood
Connate Water Saturation = 22 percent
Gas Saturation = 8 percent
Oil Saturation = 70 percent
Residual Oil Saturation = 31 percent
Oil Viscosity = 0.3 centipoise
Oil Formation Volume Factor = 1.57 RB/STB
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Example (con’t.)
Total Unit
Pore Volume = 350,000 MB
Cumulative Oil Production Since Start of Injection
= 40,000 MSTB
Current Volumetric Sweep Efficiency = 0.552
Remaining Oil Production under Current Operations
= 5,000 MB
Estimated Waterflood Ultimate Recovery = 45,000 MSTB
Ultimate Volumetric Sweep Efficiency under Current Operations
= 0.600
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0.2
0.4
0.6
0.8
1
0 10 20 30 40 50 60 70 80
Production Since Start of Waterflood, Np, MMSTB
Cumulative Oil Production = 40.0 MMSTBRemaining Oil Production = 5.0 MMSTBEstimated Ultimate Recovery = 45.0 MMSTB
26.0 MMSTB0.85vwE
Volumetric Sweep Efficiency for Waterflood Project(Pore Volume Based on 6.0% Porosity Cutoff)
vwE
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0.2
0.4
0.6
0.8
1
0 10 20 30 40 50 60 70 80
Production Since Start of Waterflood, Np, MMSTB
Cumulative Oil Production = 40.0 MMSTBRemaining Oil Production = 5.0 MMSTBEstimated Ultimate Recovery = 45.0 MMSTB
26.0 MMSTB
0.85vwE 8.4MMSTB
10% Porosity Cutoff
6% Porosity Cutoff
Volumetric Sweep Efficiency for Waterflood Project(Pore Volume Based on 6.0% and 10.0% Porosity Cutoff)
vwE
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What’s the Secret forMaximizing EA and EV (and EVOL)?
IT’S THE INJECTION WELL!
– Properly Locate the Injection Well
– Develop an Appropriate Pattern!
– Inject Water where You Find the Oil!
– Measure and Manage Injection Profiles
– Keep Fluid Levels in a Pumped Off Condition
– Balance Injection and Withdrawals
Remember the Quarterback!
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SHIFTING GEARS
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Net Pay
Static OOIP Dynamic OOIP
Drive Mechanism Controlled by Cutoffs
Permeability Distribution between Flow Units (Dykstra-Parson Coefficient)
Oil/Water Relative Permeability Mobility Ratio (Oil and Water Viscosity) Fluid Saturations at Start of Injection (So, Sg, Swc) Water Cut Economic Limit
![Page 30: Reservoir Management Under Water Injection A Worldwide Perspective Dr. William M. Cobb Dallas, Texas 2 nd National Meeting on Secondary and Assisted Oil.](https://reader036.fdocuments.us/reader036/viewer/2022081514/5517afe55503460e6e8b61dd/html5/thumbnails/30.jpg)
Permeability Cutoff Using the Watercut Method at a 95 Percent
Watercut Economic Limit
80 Acre Pattern
Dykstra-Parsons, V Sg = 0% Sg = 10%
0.6 0.24 1.10
0.7 0.71 3.30
0.8 1.20 5.60
50 20mdk
SPE-48952
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CHANGINGHORSES
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AssumeGas Fillup has been Achieved (Reservoir contains oil
and waterReservoir Pressure is Approximately Constant (Bo is
constant)Steady State Flow Prevails (Approximately)
ConclusionWater Injection = Liquid Production (at Reservoir
Conditions)
Decline Curve Analysis
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Decline Curve Analysis
* * * * (1 )
* *
w inj o w inj wo
o o
w inj ww
w
i E f i E fq
B B
i E fq
B
Fact:
Conculsion:Oil and Water Production Rates are directly related to injection rates. Therefore, DCA of qo vs t or qo vs Np must be evaluated only after giving consideration to historical and projected water injection rates.
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Latin American Waterflood
0
500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
10,000 12,000 14,000 16,000 18,000 20,000 22,000 24,000 26,000 28,000 30,000
Cum. Oil - MBO
BO
PD
BOPD
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Latin American Waterflood
0
500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
10,000 12,000 14,000 16,000 18,000 20,000 22,000 24,000 26,000 28,000 30,000
Cum. Oil - MBO
BO
PD
0
5
10
15
20
Wat
er In
ject
ion
- M
BW
PD
BOPD
MBWiPD
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Latin American Waterflood
0
500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
10,000 12,000 14,000 16,000 18,000 20,000 22,000 24,000 26,000 28,000 30,000
Cum. Oil - MBO
BO
PD
0
5
10
15
20
Wat
er In
ject
ion
- M
BW
PD
BOPD
MBWiPD
![Page 37: Reservoir Management Under Water Injection A Worldwide Perspective Dr. William M. Cobb Dallas, Texas 2 nd National Meeting on Secondary and Assisted Oil.](https://reader036.fdocuments.us/reader036/viewer/2022081514/5517afe55503460e6e8b61dd/html5/thumbnails/37.jpg)
WOR is Independent of Injection Rate
0
. .
* *
* * (1 )
(1 )
( ) *(1 )
w
w inj w
w inj w
w
w
w oSTD COND
w w
qWOR
q
i E fWOR
i E f
fWOR
f
f BWOR
f B
Conclusion:WOR is independent of injection rateWOR should be applied to individual wells and not
fieldWOR should be applied using values greater than 2.0
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Latin American Waterflood
1
10
100
0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 40,000
Cum. Oil - MBO
Pro
du
cin
g W
OR
WOR
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Keep Life SimpleKeep Life Simple
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Production Centered 5-Spot PatternProduction Centered 5-Spot Pattern
N-Well
C-WellW-Well
S-Well
E-Well
80 Acres
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0.0
1.0
2.0
3.0
4.0
5.0
6.0
7.0
8.0
1982 1984 1986 1988 1990 1992 1994 1996 1998 2000 2002 2004
MB
BL
/MO
NT
H
0
4000
8000
12000
16000
20000
24000
28000
32000
GO
R, S
CF
/BO
OilWtrWtr InjGOR
MONUMENT BUTTE UNIT-MB FED 10-35 - ProductionNorth American Waterflood – Pattern 35-10
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0.0
1.0
2.0
3.0
4.0
5.0
6.0
7.0
0.0 50.0 100.0 150.0 200.0 250.0 300.0 350.0 400.0 450.0 500.0
Cumulative Oil, MBO
Oil
Rat
e, M
BO
/Mo
nth
MONUMENT BUTTE UNIT-MB FED 10-35 - Oil Rate vs. Cumulative OilNorth American Waterflood – Pattern 35-10
E-i
W-i
S-i
N-i
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0.1
1.0
10.0
0.0 50.0 100.0 150.0 200.0 250.0 300.0 350.0 400.0 450.0 500.0
Cumulative Oil, MBO
WO
R
MONUMENT BUTTE UNIT-MB FED 10-35 - WOR vs Cumulative Oil North American Waterflood – Pattern 35-10
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A Friendly Reminder Waterflood Operations
• Cartesian Plots of Oil Rate versus Cumulative Oil Production Should Be Prepared on A Well Basis
• Semi-log Plots of WOR versus Cumulative Oil Production Should Be Prepared on A Well basis
• Preparation of the Above Two Plots For The Entire Field Gives an Average Result Which May be Optimistic or Pessimistic
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Have there been Recent Developments in Waterflooding Technology??
•NO !
& YES ! ? ? ? ?
BUT . . .
• Improved application of old principles leads to better recovery
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What Are the Key Elementsof a Successful Waterflood?
• High Moveable Oil Saturation
• Moderate to Low Oil Viscosity
• Favorable Relative Permeability
• Low Permeability Variation
• Symmetrical Patterns
• Ability to Inject Large Volumes of Water
• Ability to Lift Large Volumes of Produced Water
• Pumped Off Producing Wells
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What are the Pitfalls ofWaterflooding Practices?
• Failure to keep producing wells in pumped off condition
• Failure to clearly distinguish between Static OOIP and Dynamic OOIP (Primary vs Secondary)
• Failure to collect sufficient quantity and quality of reservoir data
• Failure to timely convert oil wells to injection wells
• Failure to monitor injection water quality
• Failure to keep the Ax sharp
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Summary ofNew Waterflood Paradigms
• Remember the Quarterback (The Injector)
• Keep the End in Mind (Maximize Volumetric Sweep)
• Keep the Ax Sharp (SPE meetings, SPE-TIGS, and SPE.org
provide great opportunities to sharpen the mind!)
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Pretty Please with Sugar!Pretty Please with Sugar!
Keep Life SimpleKeep Life Simple
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One Well Field - Latin America
0
10
20
30
40
50
60
70
80
90
100
110
120
130
140
1/1/
80
1/1/
81
1/1/
82
1/1/
83
1/1/
84
1/1/
85
1/1/
86
1/1/
87
1/1/
88
1/1/
89
1/1/
90
1/1/
91
1/1/
92
1/1/
93
1/1/
94
1/1/
95
1/1/
96
1/1/
97
1/1/
98
1/1/
99
1/1/
00
1/1/
01
1/1/
02
1/1/
03
1/1/
04
1/1/
05
0
0.2
0.4
0.6
0.8
1
1.2
1.4
BOPD BWPD MCFPD WCUT GOR
Oil
(BO
PD
); W
ater
(B
WP
D);
Ga
s (M
CF
PD
); W
C%
GO
R
Field Analysis – Latin America
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One Well Field - Latin America
0
10
20
30
40
50
60
70
80
90
100
Oil
Pro
du
ctio
n, B
OP
D
BOPD
Field Analysis – Latin America
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One Well Field - Latin America
0
10
20
30
40
50
60
70
80
90
100
1/1/
80
1/1/
82
1/1/
84
1/1/
86
1/1/
88
1/1/
90
1/1/
92
1/1/
94
1/1/
96
1/1/
98
1/1/
00
1/1/
02
1/1/
04
Wat
er P
rod
uct
ion
, BP
D
BWPD
Field Analysis – Latin America
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One Well Field - Latin America
0
10
20
30
40
50
60
70
80
90
100
1/1/
80
1/1/
82
1/1/
84
1/1/
86
1/1/
88
1/1/
90
1/1/
92
1/1/
94
1/1/
96
1/1/
98
1/1/
00
1/1/
02
1/1/
04
Wat
er P
rod
uct
ion
, BP
D
BOPD BWPD BWPD
Field Analysis – Latin America
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One Well Field - Latin America
0
0.5
1
1.5
2
1/1/
80
1/1/
82
1/1/
84
1/1/
86
1/1/
88
1/1/
90
1/1/
92
1/1/
94
1/1/
96
1/1/
98
1/1/
00
1/1/
02
1/1/
04
GO
R, M
SC
F/B
O
GOR
Field Analysis – Latin America
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One Well Field - Latin America
0
10
20
30
40
50
60
70
80
90
100
1/1/
80
1/1/
82
1/1/
84
1/1/
86
1/1/
88
1/1/
90
1/1/
92
1/1/
94
1/1/
96
1/1/
98
1/1/
00
1/1/
02
1/1/
04
Oil
Pro
du
ctio
n, B
OP
D
0
0.2
0.4
0.6
0.8
1
1.2
1.4
1.6
1.8
2
GO
R, M
SC
F/B
O
BOPD GOR
Field Analysis – Latin America
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One Well Field - Latin America
1
10
100
1/1/
80
1/1/
82
1/1/
84
1/1/
86
1/1/
88
1/1/
90
1/1/
92
1/1/
94
1/1/
96
1/1/
98
1/1/
00
1/1/
02
1/1/
04
1/1/
06
1/1/
08
1/1/
10
1/1/
12
1/1/
14
1/1/
16
1/1/
18
1/1/
20
1/1/
22
1/1/
24
Oil
Pro
du
ctio
n, B
OP
D
BOPD
Field Analysis – Latin America
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One Well Field - Latin America
0
10
20
30
40
50
60
70
80
90
100
010
020
030
040
050
060
070
080
0
Cum Oil - MBO
Oil
Pro
du
ctio
n, B
OP
D
EUR @ 10 BOPD = 625MBO
Field Analysis – Latin America
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Reservoir ManagementReservoir ManagementUnder Water InjectionUnder Water Injection
A Worldwide PerspectiveA Worldwide Perspective
Dr. William M. Cobb
Dallas, Texas
2nd National Meeting on Secondary and Assisted Oil Recovery
September 8–9, 2005
Malargue, Argentina