Transcript Pembina Cardium MFHWs - Tight Oil Consortium

© TOC, 2011
T
O
C
Production Analysis of Western
Canadian Unconventional Light Oil
Plays (SPE 149005)
C.R. Clarkson and P.K. Pedersen
Outline
• ULO Classification: plays chosen for analysis
• Pembina Cardium (Halo Play) MFHW Analysis
• Viewfield Bakken (Tight Oil) MFHW Analysis
• 2WS (Shale Oil) Vertical Well Analysis
• Conclusions and Future Work
2
ULO Classification: plays chosen
Modified from Clarkson and Pedersen (2011), SPE 149005
TIGHT OIL
HALO OIL
• Low matrix k (< 0.1 md)
• Analogous to tight gas
• Source ≠ reservoir
• Clastics or Carbonates
• High matrix k (> 0.1 md)
• Bypassed pay or stepouts
• Source ≠ reservoir
• Clastics or carbonates
Ex. Bakken, Montney
Ex. Cardium, Viking
UNCONVENTIONAL
LIGHT OIL
SHALE OIL
• Very low matrix k
• Analogous to shale gas
• Source = reservoir
Ex. 2WS, Duvernay, Muskwa
Classification of Unconventional Light Oil plays in Western Canada. 2WS stands for 2 nd White Speckled Shale
3
Halo Oil: Pembina Cardium
Modified from Bustin, Bustin and Cui, 2008
4
2500
200
2000
150
1500
100
1000
50
500
0
0
0
100
200
300
400
b)
Gas (Mscf/D) or Oil (STB/D)
250
GOR (scf/STB) or Pwf (psia)
Gas (Mscf/D) or Oil (STB/D)
a)
60
1500
40
1000
20
500
0
0
0
500
100
200
Time, days
Gas Rate
Gas (Mscf/D) or Oil (STB/D)
500
Time, days
GOR
c)
400
Pwf
Oil Rate
250
2500
200
2000
150
1500
100
1000
50
500
0
0
0
100
200
300
400
Gas Rate
GOR
Pwf
GOR (scf/STB) or Pwf (psia)
Oil Rate
300
GOR (scf/STB) or Pwf (psia)
Halo Oil: Pembina Cardium MFHWs
500
Time, days
GORBustin, Bustin
Pwf
Modified from
and Cui, 2008
Production and flowing pressure data for multi-fractured horizontal wells CARD-1 (a), CARD-2 (b) and CARD-3 (c).
Oil Rate
Gas Rate
5
Halo Oil: Pembina Cardium MFHWs
a)
b)
1.00E+03
1.00E+03
Late Linear flow?
dp/qo (psi/STB/D)
dp/qo (psi/STB/D)
Boundary-Dominated flow
1.00E+02
Late Linear flow?
1.00E+01
1.00E+00
1.00E+02
1.00E+01
1.00E+00
1
10
100
1000
1
10
Time , days
c)
100
1000
Time, days
1.00E+03
dp/qo (psi/STB/D)
Boundary-Dominated flow?
1.00E+02
Late Linear flow?
1.00E+01
1.00E+00
1
10
100
1000
Time, days
Modified from Bustin, Bustin and Cui, 2008
Log-Log diagnostic plots for multi-fractured horizontal wells CARD-1 (a), CARD-2 (b) and CARD-3 (c). Blue line on loglog plot (b) is a ½ slope line.
6
Halo Oil: Pembina Cardium MFHWs
a)
3.0E+02
4.0E+01
3.0E+01
[pi-pwf]/qo
[pi-pwf]/qo
Late Linear Flow Plot
b)
Late Linear Flow Plot
2.0E+01
2.0E+02
1.0E+02
1.0E+01
0.0E+00
0.0E+00
0
50
100
0
150
100
150
Superposition Time
Superposition Time
c)
50
Late Linear Flow Plot
[pi-pwf]/qo
4.0E+01
3.0E+01
2.0E+01
1.0E+01
0.0E+00
0
50 Modified
150 Cui, 2008
from 100
Bustin, Bustin and
Superposition Time
Linear flow analysis plots for multi-fractured horizontal wells CARD-1 (a), CARD-2 (b) and CARD-3 (c).
7
Halo Oil: Pembina Cardium MFHWs
Flowing Material Balance
Normalized Rate
1.5E-01
1.0E-01
5.0E-02
0.0E+00
0
200000
400000
600000
800000
1000000
1200000
Normalized Cumulative Production, STB
Flowing material balance plot for multi-fractured
horizontal
well
CARD-1.
Modified from Bustin,
Bustin
and
Cui, 2008
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Halo Oil: Pembina Cardium MFHWs
Linear Flow Type-Curves
Linear Flow Type-Curves
b)
100
10
10
(ye/xe) qD
100
1
0.1
0.01
0.0001
1
0.1
0.01
0.001
0.01
0.1
tDye
1
10
c)
100
0.0001
0.001
0.01
0.1
tDye
1
10
100
Linear Flow Type-Curves
100
10
(ye/xe) qD
(ye/xe) qD
a)
1
0.1
Modified from Bustin, Bustin and Cui, 2008
0.01
0.0001
0.001
Type-curve analysis of multi-fractured
0.01
0.1
1
10
tDye
horizontal wells CARD-1 (a),
100
CARD-2 (b) and CARD-3 (c).
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Halo Oil: Pembina Cardium MFHWs
b)
100
Production Rates - 2 Linear+ Model
1000
100000
100
10000
10
10
1
1
1
10
100
1000
1000
0
100
200
300
400
500
Time, days
Time, days
Actual Oil Rate
Actual Oil Rate
Oil Cumulative Production, STB
Production Rates - 2 Linear+ Model
1000
Oil Rate, STB/D
Oil Rate, STB/D
a)
Model Oil Rate
Actual Oil Cum.
Model Oil Cum.
Model Oil Rate
History-match of CARD-1 using analytical flow model (a) log-log plot and (b) semilog plot.
Modified from Bustin, Bustin and Cui, 2008
10
Halo Oil: Pembina Cardium MFHWs
b)
100
Production Rates - 2 Linear+ Model
1000
10
100000
100
10000
10
1
1
1
10
100
1000
1000
0
100
Time, days
300
400
500
Model Oil Rate
Actual Oil Cum.
Model Oil Cum.
Model Oil Rate
2-Phase Forecast
c)
200
Time, days
Actual Oil Rate
Actual Oil Rate
2-Phase Forecast
d)
1000
1000
qo and qg, STB/D or Mscf/D
qo and qg, STB/D or Mscf/D
Oil Cumulative Production, STB
Production Rates - 2 Linear+ Model
1000
Oil Rate, STB/D
Oil Rate, STB/D
a)
100
10
100
10
10
100
Time, days
Actual Oil Rate
Actual Gas Rate
CARD-3
using single-phase
1000
0
100
200
300
400
Time, days
Rate
Actual
Gas Rate
flow
model
shown
(a) Actual
log-log
plot
and (b)
semilog
Modified
from
Bustin,on
Bustin
andOilCui,
2008
500
History-match of
analytical
plot.
Oil Rate
Model Gas
Model Oil Rate
Model Gas
Also illustrated is Model
a history-match
using
a Rate
2-phase (oil+gas) tank model with a horizontal
well IPR shown
onRate
(c) loglog plot and (c) semilog plot.
111
Tight Oil: Viewfield Bakken
Modified from Bustin, Bustin and Cui, 2008
111
10000
100
1000
10
100
1
10
0
500
1000
b)
Gas (Mscf/D) or Oil (STB/D)
1000
GOR (scf/STB) or Pwf (psia)
Gas (Mscf/D) or Oil (STB/D)
a)
1000
10000
100
1000
10
100
1
10
0
1500
500
Gas Rate
1500
Time, days
Time, days
Oil Rate
1000
GOR (scf/STB) or Pwf (psia)
Tight Oil: Viewfield Bakken MFHWs
GOR
Pwf
Oil Rate
Gas Rate
GOR
Pwf
Production and flowing pressure data for multi-fractured horizontal wells BAKK-1 (a) and BAKK-2 (b).
Modified from Bustin, Bustin and Cui, 2008
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Tight Oil: Viewfield Bakken MFHWs
a)
b)
Late Linear Flow Plot
1.00E+03
boundary flow
1.00E+02
linear flow
[pi-pwf]/qo
dp/qo (psi/STB/D)
4.0E+01
3.0E+01
2.0E+01
1.00E+01
1.0E+01
1.00E+00
10
100
1000
10000
0.0E+00
Time, days
0
100
200
300
400
500
Superposition Time
c)
Flowing Material Balance
Normalized Rate
2.5E-01
2.0E-01
1.5E-01
1.0E-01
5.0E-02
0.0E+00
0
1000000
2000000
3000000
4000000
5000000
6000000
Normalized Cumulative Production, STB
Modified from Bustin, Bustin and Cui, 2008
Log-Log diagnostic plot (a), late-linear flow plot (b) and flowing material balance plot for BAKK-1. Blue line on log-log
plot (a) is a ½ slope line.
14
Tight Oil: Viewfield Bakken MFHWs
Production Rates - 2 Linear+ Model
b) 1000
100
1000000
100
100000
10
10
1
1
10
100
1000
10000
10000
0
500
1000
1500
Time, days
Time, days
Actual Oil Rate
Actual Oil Rate
Oil Cumulative Production, STB
Production Rates - 2 Linear+ Model
Oil Rate, STB/D
Oil Rate, STB/D
a)1000
Model Oil Rate
Actual Oil Cum.
Model Oil Cum.
Model Oil Rate
History-match of BAKK-1 using analytical flow model (a) log-log plot and (b) semilog plot.
Modified from Bustin, Bustin and Cui, 2008
15
Reservoir heterogeneity apparent
No reservoir heterogeneity apparent
Regional map showing trends in 2WS production. Oil production rates
(green) and GOR plots
(red)
areBustin,
shown
for several
Modified
from
Bustin
and Cui,wells.
2008 Multi-segment
Arps decline curves are fit to the oil production to assist with EUR
estimates.
16
15
100000
1000
10000
100
1000
10
100
1
10
0
1000
2000
3000
4000
1.00E+03
dp/qo (psi/STB/D)
Gas (Mscf/D) or Oil (STB/D)
10000
GOR (scf/STB) or Pwf (psia)
Shale Oil: 2WS Vertical Wells
Matrix -dominated flow?
1.00E+02
Fracture-dominated flow
1.00E+01
1.00E+00
10
Time, days
100
1000
10000
Time , days
Oil Rate
Gas Rate
GOR
Pwf
Oil and Gas production from vertical well 2WS-1 (a) and log-log plot (b) used to analyze oil production signature.
Blue line on log-log plot (b) is a ½ slope line.
Modified from Bustin, Bustin and Cui, 2008
17
Shale Oil: 2WS Vertical Wells
Early Radial Flow Plot
a)
Late Linear Flow Plot
b)
3.0E+02
1.0E+02
[pi-pwf]/qo
[pi-pwf]/qo
8.0E+01
6.0E+01
2.0E+02
4.0E+01
1.0E+02
2.0E+01
0.0E+00
0.0E+00
0
2
4
6
0
8
500
1000
1500
Superposition Time
Superposition Time
c)
Flowing Material Balance
Normalized Rate
1.5E-01
1.0E-01
5.0E-02
0.0E+00
0
1000000
2000000
3000000
4000000
5000000
Normalized Cumulative
Production,
STB
Modified
from Bustin,
Bustin and Cui, 2008
Rate-transient analysis of 2WS-1: (a) early-radial flow analysis; (b) late (matrix) linear flow analysis and (c)
flowing material balance analysis.
18
Shale Oil: 2WS Vertical Wells
b)
Production Rates - Transient DP Model
Production Rates - Transient DP Model
1000
1000000
100
100000
10
10000
Oil Rate, STB/D
Oil Rate, STB/D
100
10
1
1
0.1
10
100
1000
10000
1000
0
1000
2000
3000
4000
5000
Time, days
Time, days
Actual Oil Rate
Actual Oil Rate
Oil Cumulative Production, STB
a)1000
Model Oil Rate
Actual Oil Cum.
Model Oil Cum.
Model Oil Rate
History-match of 2WS-1 using analytical flow model (a) log-log plot and (b) semilog plot.
Modified from Bustin, Bustin and Cui, 2008
19
Shale Oil: 2WS Vertical Wells
a)
b)
2-Phase Forecast
2-Phase Forecast
1000
qo and qg, STB or Mscf/D
qo and qg, STB or Mscf/D
1000
100
10
10
100
1000
10000
Time, days
Actualqo
AnalyticalModelqo
NumericalModelqo
Actualqg
AnalyticalModelqg
NumericalModelqg
100
10
0
500
1000
1500
Time, days
Actualqo
AnalyticalModelqo
NumericalModelqo
2000
2500
Actualqg
AnalyticalModelqg
NumericalModelqg
History-match of gas and oil production for 2WS-1 vertical well using a numerical model (solid lines) and tank model
(dashed lines) shown on (a) log-log plot and (b) semilog plot.
Modified from Bustin, Bustin and Cui, 2008
20
Shale Oil: 2WS Vertical Wells
b)
2-Phase Forecast
1000
2-Phase Forecast
1000
qo and qg, STB or Mscf/D
qo and qg, STB or Mscf/D
a)
100
10
10
100
1000
10000
Time, days
Actualqo
AnalyticalModelqo
NumericalModelqo
Actualqg
AnalyticalModelqg
NumericalModelqg
100
10
0
500
1000
1500
Time, days
Actualqo
AnalyticalModelqo
NumericalModelqo
2000
2500
Actualqg
AnalyticalModelqg
NumericalModelqg
History-match of gas and oil production for 2WS-1 vertical well using a numerical model (solid lines) and tank model
(dashed lines) shown on (a) log-log plot and (b) semilog plot. A single porosity model was used.
Modified from Bustin, Bustin and Cui, 2008
21
Shale Oil: 2WS Vertical Wells
3.5E+05
y = 0.0319x + 9071.5
R² = 0.8025
3.0E+05
EUR, STB
2.5E+05
2.0E+05
1.5E+05
1.0E+05
5.0E+04
0.0E+00
0.0E+00
2.0E+06
4.0E+06
6.0E+06
8.0E+06
1.0E+07
Matrix Surface Area, ft 2
Relationship between matrix surface area, as established from late linear flow, and EUR for several 2WS vertical
wells. A matrix permeability of 150 nd was assumed in the analysis.
22
Cardium: PLE Match to MFHW
Power-Law Exponential
Cartesian Plot - q vs. time
Power-Law Exponential
Log-log Plot - q vs. time
1.E+03
0.20
1.E+03
qo_STB/day_(PLE)
0.18
qo_STB/day_all
qo_STB/day_edited
0.14
0.12
1.E+02
0.10
0.08
0.06
0.04
qg, MSCF/day
or qo, STB/day
0.16
Gp, BSCF or Np, MMSTB
qg, MSCF/day
or qo, STB/day
qo_STB/day_(PLE)
qo_STB/day_all
qo_STB/day_edited
Np_MMSTB_(PLE)
Np_MMSTB_edited
Np_MMSTB_all
1.E+02
1.E+01
0.02
1.E+01
0.00
200
400
600
800
1.E+00
1,000
1.E+00
1.E+01
Time, Days
Power-Law Exponential
q vs. Gp or Np
1.E+03
1.E+04
Power-Law Exponential
D- and b-parameters
1.E+01
500
D_wo_Dinf
D_w_Dinf
D=1/q*dq/dt
D=dq/dNp
b_wo_Dinf
b_w_Dinf
b=d/dt*1/D
b=d/dt*1/D from Np
qo_STB/day_(PLE)
450
qo_STB/day_all
1.E+00
qo_STB/day_edited
1/Loss Ratio (D), 1/days
400
350
qg, MSCF/day
or qo, STB/day
1.E+02
Time, Days
300
250
200
150
100
1.E-01
1.E+03
1.E+02
1.E+01
1.E-02
1.E+00
1.E-03
1.E-01
1.E-04
1.E-02
Loss Ratio Derivative (b)
0
50
0
0.00
1.E-05
0.02
0.04
0.06
Gp, BSCF or Np, MMSTB
0.08
0.10
1.E+00
1.E-03
1.E+01
1.E+02
1.E+03
Time, Days
1.E+04
1.E+05
23
Conclusions
• For the Halo Oil example analyzed (Pembina Cardium), the data
quality was sufficient to yield reasonable estimates of OOIP, and
effective wellbore length
• Only public data (ex. monthly production) were available for the Tight
Oil (Viewfield Bakken) and Shale Oil (Second White Specs) plays, so
extracted information is qualitative
• We are starting to develop techniques to allow analysis of multiphase flow and demonstrated the utility of a multi-phase analytical
(tank) model for providing preliminary estimates of reservoir
properties prior to more rigorous numerical simulation
• We have created a correlation between vertical well EUR and
contacted matrix surface area for the 2WS wells analyzed that would
suggest that multi-fractured horizontal wells could work in the
unstructured portions of the play if an artificially-induced contacted
matrix surface area of several million cubic feet could be created
24