1 1 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 Listening to the Reservoir – Interpreting Data from Permanent Downhole Gauges Roland N. Horne Stanford University Society of Petroleum Engineers Distinguished Lecturer Program www.spe.org/dl
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INTERPRETING DATA FOR PERMANENT DOWNHOLE GAUGE - RolandHorne.pdf
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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 Programwww.spe.org/dl
Listening to the Reservoir –
Interpreting Data from Permanent Downhole Gauges
Roland N. HorneStanford University
Society of Petroleum Engineers
Distinguished Lecturer Programwww.spe.org/dl
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• More than 10,000 installed worldwide.
• Usually installed to monitor downhole equipment.
• Data rarely applied for reservoir analysis.
Permanent Downhole Gauges (PDG)
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Reservoir Engineering Uses1. Reservoir pressure
2. Flowing bottomhole pressure management
3. Replacement for shut-in tests
4. Skin determination
5. Monitoring interference effects
6. Voidage control
7. Tubing hydraulics matching
8. Inflow performance modeling
9. Monitoring well treatments
10. History matching
Kragas, Turnbull and Francis (2004)
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Replacement of Shut-In Tests
• Northstar, Alaska
6 wells, 2 days duration
10,000 STB/d production would be lost per well
� 120,000 STB acceleration per campaign
� 650,000 STB acceleration over field life
And, $1.6 million avoided wireline costs
Kragas, Turnbull and Francis (2004)
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PDG-Specific Issues
1. Manipulation of huge volumes of data.
2. Deconvolution to see characteristic behaviors.
3. Identification of break points, to separate transients.
4. Changes (such as permeability and skin) as a function of time.
5. Flow rate information.
6. Temperature measurements.
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1. Manipulation & Processing of Data
• Data at 1 second frequency =
32 million data/year per gauge.
• Physical storage and access are a challenge even for today’s databases.
• Access, retrieval and transfer are a challenge even for today’s bandwidths.
Chorneyko (2006)
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1. Manipulation & Processing of Data
(Athichanagorn et al., 2002)
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Missing flow data
Pressure
Rate
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Denoising with Wavelets
(Athichanagorn et al., 2002)
Noisy signal
Denoised signal
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Outlier Filtering with Wavelets
(Athichanagorn et al., 2002)
Outlier pointsAcceptable points
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2. Deconvolution
• Theoretician’s playground, since 1949.
• Remained impractical until recently.
• Work of von Schroeter, Hollaender and Gringarten (2004), using nonparametric regression, p and q matching, derivative restrictions and smoothness limit constraints.
∫ −∆=∆t
w dtpqtp0
0 )().(')( τττpressure flow constant pressure
reservoir model
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2. Deconvolution
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0 5 10 15 20 25 30 35 40 45
Time, hrs
Pre
ssure
, psi
0
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Flo
w r
ate
, bb
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ay
Nomura (2006)
45 hours of data, no transient longer than 5 hours
events
5 hours
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2. Deconvolution
Nomura (2006)
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10
100
0.001 0.01 0.1 1 10 100
Time, hrs
Pre
ssure
derivative,
psi
TRUE
case1
case2
case3
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2820
0 5 10 15 20 25 30 35 40 45
Time, hrs
Pre
ssu
re, psi
0
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Flo
w r
ate
, bbl/day
45 hour response, inferred from deconvolution
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2. Deconvolution – Issues
• Model may change over time.
• Buildups and drawdowns may be different.
– Levitan (2005): shut-ins only
– Olsen & Nordvedt (2006): shut-ins only
• Strong dependence on break points.
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3. Transient Identification – Break Points
Wavelet approach: Athichanagorn et al. (2002)
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Time, hrs
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ssur
e, p
si
Nomura (2006)
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3. Break Points and Deconvolution
Nomura (2006)
1
10
100
0.001 0.01 0.1 1 10 100
Time, hrs
Pre
ss
ure
de
riv
ati
ve
Wavelet
Adjusted
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Inaccurate break points are fatal for deconvolution
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3. Break Points and Rate Normalization
Houzé (2006)
Inaccurate break points are also problematic for rate normalization
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3. Break Points – Approaches
• Wavelets often used for ‘first round’.
• Khong (2001): statistical method.
• Rai (2005 and 2007): – Savitzky-Golay smoothing filter
• Richardson, Roux, Quinn, Harker and Sides (2002)
• Lee (2003)
• Haddad, Proano and Patel (2004)
• Coludrovich, McFadden, Palke, Roberts and Robson (2004)
• Chorneyko (2006)
• Olsen and Nordtvedt (2006)
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4. k and s Changes
• de Oliviera and Kato (2004): “analytical models used traditionally for conventional well test interpretation may be too simple to define the pressure and flow rate transients that occur during the extended duration of a permanent downhole gauge record.”
• Using full-scale numerical models is probably what we need, but not widely applied (yet).
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5. Downhole Flow Rate Gauges
• Both p and q contain measurement errors.
• Match both simultaneously.
• von Schroeter, Hollaender and Gringarten(2004)
• Nomura (2009)
• Ahn and Horne (2008)
2
1
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)(2
1qaDbRpdobj
cn
r
r
rrrrr−++−= ∑
=
µλ
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5. Downhole Flow Rate Gauges
Ahn (2008)
450 500 550 600 6508894
8896
8898
8900
8902
8904
8906
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8910
Time (seconds)
Pre
ssure
[psia
]
measured
iteration 1
iteration 2
iteration 3
iteration 4
450 500 550 600 6506800
7000
7200
7400
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8000
8200
8400
8600
Time (seconds)
Liq
uid
rate
[bbl/d]
measured
iteration 1
iteration 2
iteration 3
iteration 4
Pre
ssu
re (
psia
)
Ra
te (
ST
B/d
)Time (seconds)Time (seconds)
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5. Downhole Flow Rate Gauges
p
q
A B
A – flow event B – noise event
Pressure
Rate
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6. Temperature Data
Temperature respondsto flowratechanges
Temperature respondsto flowratechanges
Duru (2008)
q
T
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6. Temperature Data
Duru and Horne (2008)
Match temperaturehistory ���� porosity
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Concluding Remarks (1)
• Permanent downhole gauges are rich sources of reservoir data.
• Not just more, but better!
• Good progress on:– Noise and outlier removal
– Break point identification
– Deconvolution
– Combining rate data
– Utilizing temperature data
• But, more work to do!
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Concluding Remarks (2)
• The ultimate goal is to achieve a high degree of automation.
• Nobody wants to look at 100 million data points!
• Eventual inclusion in SmartFieldsprocedures.
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Acknowledgements
• Members of the SUPRI-D research consortium on innovation in reservoir testing.
• SUPRI-D graduates:
– Athichanagorn (1999)
– Khong (2001)
– Lee (2003)
– Rai (2005)
– Nomura (2006)
– Duru (2008)
– Ahn (2008)
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SPE Distinguished Lecturer Program
The SPE Distinguished Lecturer Program is funded principally through a grant from the SPE Foundation.
The society gratefully acknowledges the companies that support this program by allowing their professionals to participate as lecturers.
Special thanks to the American Institute of Mining, Metallurgical, and Petroleum Engineers (AIME) for its contribution to the program.
Society of Petroleum Engineers
Distinguished Lecturer Programwww.spe.org/dl
17
33
Society of Petroleum Engineers
Distinguished Lecturer Programwww.spe.org/dl 33
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