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Transcript of The SPE Foundation through member donations and a ... · PDF fileThe SPE Foundation through...
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Primary funding is provided by
The SPE Foundation through member donations
and a contribution from Offshore Europe
The Society is grateful to those companies that allow their
professionals to serve as lecturers
Additional support provided by AIME
Society of Petroleum Engineers
Distinguished Lecturer Program www.spe.org/dl 1
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Unconventional Reservoirs Require Unconventional Analysis
Techniques
David Anderson
Society of Petroleum Engineers
Distinguished Lecturer Program www.spe.org/dl
2
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3
This Presentation…
Introduction to rate transient analysis (RTA)
The challenge of analyzing unconventionals
Current methodologies – how has the technology
evolved?
The future of production analysis and modeling
Probabilistic approach
Field examples
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4
Rate Transient Analysis (RTA) is the science (and art) of extracting useful information about the reservoir, completion and/or surface operations based on the interpretation, analysis and modeling of continuous measurements of production volumes and flowing pressures from a single well.
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5
Concept of Rate Transient Analysis
W ell 01
Company: On Stream: 03/28/2013Field: Current Status: Flowing
Gp: 1775 MMscfNp: 0.000 MstbWp: 0.000 MstbQcond: 0.000 Mstb
3600
-1200
-800
-400
0
400
800
1200
1600
2000
2400
2800
3200
Op
Gas R
ate
(M
scfd
)
5200
0
400
800
1200
1600
2000
2400
2800
3200
3600
4000
4400
4800
Ru
n D
ep
th P
ressu
re (p
si(a
))
480 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46
Normalized Time (month)
- Production occurs under
changing constraints
- Reservoir “signal” may be in
rates or pressures (or both)
q (
Mscfd
) pw
f (psia
)
Time (days)
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6
Concept of Rate Transient Analysis
Comparison View
10 -5
10 -4
10 -3
9 . 10 -3
2
3
4
6
2
3
4
6
2
3
4
6
No
rma
lize
d G
as
Ra
te (
MM
sc
fd/p
si)
160 0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150
MBT
160 0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150
Normalized Time (month)
Legend Normalized Gas Rate vs. Normalized Time
Normalized Gas Rate vs. MBT (2)
Instantaneous normalization
Superposition (Material Balance Time)
q/D
p (
Mscfd
/psi)
Time, Material Balance Time (months)
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7
Type Curve Analysis – Characterize Reservoir
Comparison View
10-5
10-4
10-3
10-2
10-1
1.0
2 . 100
5 . 10-6
2
4
2
4
2
4
2
4
2
4
No
rmalized
Gas R
ate
(M
Mscfd
/psi)
10-4
10-3
10-2
10-1
1.0
4 . 100
2 . 10-5
3
5
2
4
2
4
2
4
2
4
2
q/D
(M
Mscfd
/(10
6p
si2
/cP
))
10-3 10-2 10-1 1.0 101 102 103 104 7 . 1043 . 10-4 5 6 2 3 4 5 6 2 3 4 5 6 2 3 4 5 6 7 2 3 4 5 6 2 3 4 5 6 2 3 4 5 6 2 3 4 5 6 2 3
MBT
10-2 10-1 1.0 101 102 103 104 105 8 . 1052 3 4 5 6 7 2 3 4 5 6 2 3 4 5 6 2 3 4 5 6 2 3 4 5 6 2 3 4 5 6 7 2 3 4 5 6 2 3 4
tca (d)
Legendq/D - TC
Normalized Gas Rate vs. MBTLog-Log Plot
- Identify flow regimes
Transient Flow
(permeability, skin)
Boundary Dominated Flow
(connected HCPV)
q/D
p (
Mscfd
/psi)
Material Balance Time (days)
Adapted from Palacio and Blasingame: “Decline-Curve
Analysis Using Type Curves” (SPE 25909) 1993
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8
Flowing Material Balance – Estimate HCPV
Example 1
Company: On Stream: 10/01/2002Field: ApolloCurrent Status: Unknown
Gp: 3409 MMscfNp: 224.268 MstbWp: 16.566 MstbQcond: 0.000 Mstb
7000
0
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
5500
6000
6500
Pre
ssu
re (
psi(
a))
30
0
2
4
6
8
10
12
14
16
18
20
22
24
26
28
Op
era
ted
Gas R
ate
(M
Mscfd
)
10.500.00 0.50 1.00 1.50 2.00 2.50 3.00 3.50 4.00 4.50 5.00 5.50 6.00 6.50 7.00 7.50 8.00 8.50 9.00 9.50 10.00
Cumulative Gas Production (Bscf)
LegendGas Rate
Flowing Pressure
Measured
flowing
pressure
Measured rate
Pro
duction R
ate
(M
scfd
)
pw
f (p
sia
)
Cumulative Production (bcf)
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9
Flowing Material Balance – Estimate HCPV
Example 1
Company: On Stream: 10/01/2002Field: ApolloCurrent Status: Unknown
Gp: 3409 MMscfNp: 224.268 MstbWp: 16.566 MstbQcond: 0.000 Mstb
7000
0
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
5500
6000
6500
Pre
ssu
re, p
/Z** (
psi(
a))
30
0
2
4
6
8
10
12
14
16
18
20
22
24
26
28
Op
era
ted
Gas R
ate
(M
Mscfd
)
10.500.00 0.50 1.00 1.50 2.00 2.50 3.00 3.50 4.00 4.50 5.00 5.50 6.00 6.50 7.00 7.50 8.00 8.50 9.00 9.50 10.00
Cumulative Gas Production (Bscf)
LegendFlowing p/Z**
Gas Rate
Flowing Pressure
Original Gas-In-Place
Calculated p/z
pss
wf
qbz
p
z
p
- Mattar L., Anderson, D., Dynamic Material Balance – Oil or Gas
In Place Without Shut-ins - 2, CIPC 2005-113
Pro
duction R
ate
(M
scfd
)
pw
f and p
/z (
psia
)
Cumulative Production (bcf)
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Modeling – Validate and Forecast
Results
0.00
0.50
1.00
1.50
2.00
2.50
3.00
3.50
4.00
4.50
5.00
5.50
6.00
6.50
7.00
7.50
8.00
8.50
9.00
Cal G
as R
ate
(M
Mscfd
)
0
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
5500
6000
6500
7000
7500
8000
8500
9000
9500
10000
10500
11000
11500
Gas C
um
(M
Mscf)
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
5500
6000
6500
7000
7500
8000
8500
9000
9500
10000
Pre
ssu
re (p
si(a
))
2002 2003 2004 2005 2006
Pressure match
Production Forecast
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Benefits of RTA
Evaluation of reserves
Reliable early evaluation- choked wells
Scientific support for reserves auditors
Dynamic reservoir characterization
Estimate permeability and in-place hydrocarbons
Estimate completion effectiveness
Calibrate reservoir simulation models
Reservoir surveillance
Distinguish productivity fall-off from depletion
Identify optimization candidates
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The Challenge of Analyzing Unconventionals…
Unconventional reservoirs are more complex
Complex, non-uniform fracture networks
Reservoir properties are significantly altered by
completion
Low permeability – long term transient flow
Drainage area continually expands
Difficult to distinguish clear drainage boundaries
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Flow Characterization – Conventional vs.
Unconventional
Radial Flow - Conventional Linear Flow - Unconventional
Fluid flows to the sandface
Pressure drawdown localized
at sandface
Fluid flows to the fracture(s)
Pressure drawdown throughout
fracture(s)
High Permeability
Low Contact Area
Low Permeability
High Contact Area
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Unconventional Analysis Methods…
Square Root Time Plot- Linear Flow
q
pD
t
A = 4 nf xf h
2 xf
h
Skin btm
q
p
D
kA
fAAComplex
Simple
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Boundaries and Drainage – Conventional vs.
Unconventional
a) Conventional Reservoir b) Unconventional Reservoir
Geological features Well interference
Parallel Fractures
Parallel and Orthogonal
Fractures
15
Fracture
interference Stimulated
Reservoir Volume
(SRV)
Vertical Wells Horizontal Wells
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Unconventional Analysis Methods…
Flowing Material Balance
wf
z
p
Stimulated Reservoir Volume
2 xf
h
In-place
hydrocarbons
(SRV)
Cumulative Productioni
Le
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Unconventional Analysis Methods…
Simplified Approach-
A√k
skin
tetf = SRV
SRV
Assume – uniform fractures
Calculated- xf, k, skin, SRV
Anderson et al 2010, Analysis of Production
Data from Fractured Shale Gas Wells – SPE
131787
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W ell 02
Company: On Stream: 25/06/2013Field: Current Status: Flowing
Gp: 705 MMscfNp: 0.000 MstbWp: 0.000 MstbQcond: 0.000 Mstb
103
104
3 . 104
2
3
4
5
6
7
8
9
2
Op
Gas R
ate
(M
scfd
)
540
0
20
40
60
80
100
120
140
160
180
200
220
240
260
280
300
320
340
360
380
400
420
440
460
480
500
520
Ru
n D
ep
th P
ressu
re (p
si(a
))
June July August September October November December
2013
Illustrating the Challenge of Analyzing
Unconventionals
- Non-uniform frac length,
spacing and conductivity
- Ultra low matrix permeability
- Six months production,
constant pwf
Simulation of flow into a complex fracture network in a gas shale
q (
MM
scfd
) pw
f (psia
)
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Simplified Approach – Bulk Reservoir Properties
A√k
skin
tetf = SRV
Contacted
HCPV
SRV =
0.75 bcf
Contacted
HCPV = 1.1 bcf
Dp
/q (
psi/M
Mscfd
)
Square Root Time
q/D
p (
MM
scfd
/psi)
Time (d)
q/D
p (
MM
scfd
/psi)
Gpa/ceDp (bcf)
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Simplified Approach – Comparison of Analyzed
Reservoir Properties with Actual
Actual Hz fractures – 250 ft, FCD=50
Vert fractures – 500 ft, FCD = 100
k (matrix) = 0.0001 md
OGIP = 46 bcf (1 section)
As Analyzed Stimulated reservoir width = 120 ft
k (stimulated zone) = 0.011 md
k (matrix) = 0.0005 md
Contacted OGIP = 2 bcf
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Actual SRV ~ 0.75 bcf
As Analyzed SRV = 0.75 bcf
Simplified Approach – Comparison of Analyzed
SRV with Actual
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Comparison View
10-1
1.0
101
2 . 101
2
3
4
5
6
8
2
3
4
5
6
8
Cal G
as R
ate
(M
Mscfd
) / R
ate
Fo
recast
1 (
MM
scfd
)
0 4 8 12 16 20 24 28 32 36 40 44 48 52 56 60 64 68 72 76 80
Time (month)
2013 2014 2015 2016 2017 2018 2019
Gp = 1.8 bcf
Simplified Approach – Comparison of 5 year
Production Forecasts
Gp = 1.9 bcf
q (
MM
scfd
)
Time (years)
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23
Field Example - Bakken Oil
Bakken
Bakken OilCompany: On Stream: 06/05/2008Field: Undefined FieldCurrent Status: Flowing
Gp: 72 MMscfNp: 98.451 MstbWp: 19.879 MstbQcond: 0.000 Mstb
1.0
101
102
103
2 . 103
2
3
4
5
7
2
3
4
5
7
2
3
4
5
7
Op
Oil R
ate
(stb
/d)
Op
Wate
r R
ate
(stb
/d)
1.0
101
102
103
2
3
4
5
7
2
3
4
5
7
2
3
4
5
7
Op
Gas R
ate
(M
scfd
)
5200
0
200
400
600
800
1000
1200
1400
1600
1800
2000
2200
2400
2600
2800
3000
3200
3400
3600
3800
4000
4200
4400
4600
4800
5000
Casin
g P
ressu
re (p
si(a
))
Calc
ula
ted
San
dfa
ce P
ressu
re (p
si(a
))
Ru
n D
ep
th P
ressu
re (p
si(a
))
Tu
bin
g P
ressu
re (p
si(a
))
04 05 06 07 08 09 10 11 12 01 02 03 04 05 06 07 08 09 10 11 12 01 02 03 04 05 06 07 08 09 10
2008 2009 2010
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24
Field Example – RTA – Simplified
A√k
FCD’
tetf = SRV
Contacted HCPV = 2,800 Mstb
SRV = 850 Mstb
Dp
/q (
psi/stb
/d)
Square Root Time
q/D
p (
stb
/d/p
si)
Time (d)
q/D
p (
stb
/d/p
si)
Np/ceDp (Mstb)
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Field Example – RTA - Modeling
High efficiency “short” fracs Low efficiency “long” fracs
Ozkan et al. 2009, “Tri-Linear Flow” Stalgorova et al, 2013, “Five Region
Model”
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Provides a “bulk” reservoir interpretation
Reliable estimation of stimulated and total
connected HCPV
Identification of effective system permeability and
apparent skin damage
No unique interpretation of fracture properties
(orientation, distribution, density, length and
conductivity)
No unique interpretation of matrix permeability
Analytical models with different geometries are
available
Summary of Current Unconventional RTA
Technology
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27
The Future of Unconventional RTA –
Probabilistic Approach
Data
q, pwf
Rate Transient Analysis:
Deterministic
Modeling – Realizations of RTA results:
Probabilistic
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28
Probabilistic Well Performance Analysis
Define ranges or distributions of input parameters
Completion properties
Reservoir properties
Run the reservoir model probabilistically using Monte
Carlo simulation
Keep only history matches that meet a minimum
goodness of fit criteria
Report reservoir characteristics and production
forecasts as distributions, not single values
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29
Probabilistic Well Performance Analysis –
Forecasts
Rate vs Time Rate vs Cumulative
Expected Ultimate Recovery Original Gas in Place
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30
Conclusions
RTA provides “bulk” reservoir interpretation
Ideal for establishing connected HCPV
Assists in understanding recovery mechanism
Yields reliable production forecasts
Analyzing unconventional well production presents
significant challenges
Analysis and modeling technology has evolved
Unconventional plays are statistical in nature – many
wells must be analyzed to understand behavior
A probabilistic approach will help to manage and
communicate uncertainty
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31
Thank-you…
Questions?
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Society of Petroleum Engineers
Distinguished Lecturer Program www.spe.org/dl 32
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