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![Page 1: Comparison of 4D VSP and 4D surface seismic results ... · PDF fileComparison of 4D VSP and 4D surface seismic results, ... Nominal Stacking Fold 100 ... (Chevron), T. Daley (LBNL)](https://reader037.vdocuments.mx/reader037/viewer/2022102812/5aad881f7f8b9aa9488e67cd/html5/thumbnails/1.jpg)
With contributions from
Schlumberger
A. J. Campbell, A., Shujaat, W. S. Leaney, L. Dahlhaus,
S.Nakanishi, M. Verliac, S. Sharma,
Comparison of 4D VSP and 4D surface seismic results,
operations and costs: CO2CRC Otway project case
study
R. Pevzner1,3 , E. Caspari1,3 , V.
Shulakova2,3 , B. Gurevich1,3, M.
Urosevic1,3
1 Curtin University, 2CSIRO, 3CO2CRC
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CO2CRC Otway project• Stage I – CO2 injection into a
depleted gas reservoir
– 80/20 % of CO2/CH4 stream
produced from Buttress,
transported and injected into
CRC-1 well (initial production
well)
– 2 km depth
– 64,000 tonnes
• Stage II – CO2 injection into
saline aquifer
– Up to 10,000 tonnes
– 1.4 km depth
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The reservoir
500m
Strike direction
Pre-production 3D seismic data recorded in 2000Naylor gas field
Small, thin, heterogeneous and deep depleted gas reservoir, surrounded by
complex faulting,
CO2/CH4 – mix injected and monitored with the most sensitive seismic
techniques
N-1CRC-1
Waarre-C
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Waarre C TL effect modelling
• Acoustic inversion (using the baseline seismic data, 2008) ->
initial impedance model
• Hydrodynamic modelling -> changes in pore fluid in time
• Fluid substitution using the initial impedance model + predicted
gas saturation
• Seismic modelling using new impedance model to predict TL
effect
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Baseline data (model) and predicted
signal
2008 2010-2008
NRMS, %, 60 ms
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Stage II
• CO2/CH4 plume in saline aquifer
• Depth ~1.4 km
• Overall volume < 10,000 tonnes
• Thin, less then 200 m in diameter
High permeability case
Low permeability case
100 m
Results of hydrodynamic modelling
(10 000 tonnes of CO2, 90 days), [Y. Cinar, 2009]
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Changes of rock properties due to fluid
substitution
0 0.2 0.4 0.6 0.8 11.5
2
2.5
3
3.5
Water saturation
Velo
city,
km
/s
Vp
Vs
0 0.2 0.4 0.6 0.8 10.85
0.9
0.95
1
Water saturationR
ela
tive im
pedance c
hange
Injection of CO2 in supercritical form into saline aquifer with 25% porosity
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Time-lapse signal for the different volumes of
injected/leaked CO2 /CH4 gas mixture
3 k tonnes 2 k tonnes 1 k tonnes4 k tonnes
Tim
e (
ms
)T
ime
(m
s)
[Alonaizi et al., 2011]
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Goals of the seismic monitoring program
• Assurance (no leakage)
• Attempt to detect CO2 movement in the reservoir
• Evaluation of various time-lapse seismic monitoring techniques
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Seismic monitoring – Final program
• Time lapse 3D surface seismic
– Least sensitive and repeatable but provides coverage of entire reservoir and beyond
– Necessary for „assurance monitoring‟ to detect loss of primary containment
– No 4D effect expected in general
• Time lapse borehole seismic
– CRC-1: 3DVSP with 3C geophones (Schlumberger‟s VSI)
• Improved sensitivity and resolution relative to surface data, improved repeatability
• More chance for direct CO2 monitoring, limited coverage
– Naylor-1: Permanent downhole sensors (LBNL)
• Potentially most sensitive and repeatable
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Survey Otway 3D
Location Otway Basin, Victoria, Australia
Date 1) December 2007–January 2008
2) January 2009
Number of Source Lines 29 Lines
Number of Source Points 2181 Points
Number of Receiver Lines 10 Lines
Number of Receiver Points 873 Points
Number of Swath 2
Bin Size 10 m in-line by 10 m cross-line
Total Number of Bins 30821
Nominal Stacking Fold 100
Offset Range 50-2150 m
Receiver line orientation West-East
Source Line Orientation South-North (1-27 lines), West-
East (28-29 lines)
Source Parameters
Source Type Weight Drop (concrete breaker) – 750 kg,
free fall from 1.2 m – 2008
IVI Mini-vibe 2009
Stacking fold 4
Source Geometry
Source Line Spacing 100 m
Source point Spacing 20 m
Receiver Parameters
Receiver Type 10 Hz - geophones
Recording Pattern Orthogonal cross-spread pattern
(odd source line were recorded by
fist 5 receiver lines, even source
lines - by 6-10 receiver lines)
Receiver Line Spacing 100 m
Receiver Point Spacing 10 m
Recording Parameters
Record length 4 s
Sample Interval 1 ms – 2008, 2 ms - 2009
Recording Filters No filters were applied in the field
TL : Simultaneous acquisition of 3D surface and 3D
VSP
Source linesReceiver lines
Survey Parameters
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Seismic operations
• Time: 14 days per survey, +5 days mob/demob (surface seismic only)
• Crew:
– Seismic source (~2 persons in baseline survey operating the weight
drop vs. 3-4 persons operating the IVI minibuggy in monitor
surveys)
– GPS, real-time positioning of the seismic source – 1 person
– VSP: 1 person
– Surface seismic: 3-4 persons
– Support personnel: 1 person
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Raw data examplethe same common shot gather for 2008 (left), 2009 (middle) and
2010 (right) surveys
2008 2009 2010
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• Data input (correlation with sweep signals for 2009-2010)• Trace DC Removal
• Data equivalence and binning (bin size 10x10m)• Elevation statics (30 m, 1800 m/s)• Trace Editing• Bandpass filtering (7-10-150-160 Hz)• Spike and Burst Noise Attenuation• Automatic gain control (500 ms, applied before decon and removed after)• Spiking Deconvolution (minimum phase for 2008 and zero-phase for 2009)• Velocity Analysis (two iterations)• Residual Static Correction (Max Power Autostatics)• Radon filter in cone window (AGC 500ms applied before and remove after)• FX deconvolution before stack• Coupled Time Variant Scaling
• Pre-stack static shifts matching
• True Amplitude Recovery (spherical divergence correction as 1/(time*vel**2))• Normal Moveout Correction (30% muting)• CDP stack (mean, power scalar for stack normalization 0.5)• Post-processing (TV Whitening, FXY Deconvolution)• Explicit FD 3D Time Migration
Processing flow
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Post-stack cross-equalisation
• Window: 400-1400 ms (i.e. ABOVE the Waarre C)
• Workflow
– Cross-correlation based static shifts analysis
– Shaping filter
– Amplitude balancing
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Base-line, 2008 Monitor I, 2009 Post-injection, 2010
3D
Reservoir
Processed and cross-equalized data
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NRMS, 2008-2009, reduced geometry
STAGE 1 limit
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NRMS, 2009-2010, full geometry
STAGE 2 limit
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NRMS, 60 ms window, Paaratte
2008-2009 2009-2010, cut 2009-2010, full
Source Fold
50 100 1500 50 100 150050 100 1500
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Achieved repeatability: NRMS difference
(60 ms window) for 2010-2009 surface
seismic
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Difference volumes, reduced geometry
[Shulakova et al., 2010]
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2010-2009, full geometry
[Shulakova et al., 2010, poster]
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2008 2009-2008 2010-2009 Simulated response
7,000 t
1 km
Expected TL signal vs actual seismic
response in Paaratte
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3D VSP
• CRC-1
• Receiver interval
1500-1605 m (15 m
spacing)
• 2007/8 – Weight
drop, 1100 sp
• 2010 – IVI
minibuggy, 2200 SP
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4D VSP processing workflow (Campbell, A. & Shujaat, A. 2010)
1. Extract coincident sources and receivers
2. Regularization if necessary
3. Reconcile differing source signatures
• Trace by trace decon shapes to common signature
• Common bandpass after decon applied to fine-tune
signature
4. Model building
5. Model based residual statics
6. Cross equalization if necessary
7. Data quality based source selection
• Amplitude differences
• Residual timing differences
• 4D metrics
8. Imaging
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Processed data
2007 2010 difference
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Processed + cross-equalised
2007 2010 difference
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3D VSP, 2007, CD0, crossline 80
3D surface seismic, 2009, inline 100
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Waarre C
A B
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Waarre C amplitude
2007 2010 2010-2007
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Achieved repeatability: NRMS
difference (60 ms window) for 2010-
2008 3D VSP
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4D VSP vs 4D land surface seismic
• Coverage: VSP provides limited coverage
• Repeatability/TL signal-to-noise: VSP provides much better
repeatability
• Field operations
– Acquisition time/performance: VSP is characterized by very short
mob/demob
– Disruption to farming activities: VSP does not require distributing
cables/geophones
• Processing: VSP data processing is much faster
• Cost: surface seismic in case of Otway project was cheaper
due to non-commercial rates
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Conclusions
• Very good (post-stack) repeatability achieved combining weak and different source
types, thanks to high spatial data density and high fold
• CO2 upward migration (“Leak”) readily detectable with 3D TL seismic - no indication in
TL data (using diverse measurements and studies)
• Clear, unique TL signal from Waarre-C not observed (CO2 contained); very subtle TL
signal – sensitive to processing/cross-equalisation schemes (analysis still ongoing)
• VSP shows superior repeatability and sensitivity with respect to surface seismic (also
measure full wave field; possibility for development of alternative M&V methodologies)
• Way forward: Stage II
– 2011-2012
– Both surface 3D seismic and some borehole component
– Permanent installation
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Acknowledgements
• Kevin Dodds BP Alternative Energy of behalf of CCP
• Schlumberger: S. Nakanishi, A. J. Campbell, W. S. Leaney, L.
Dahlhaus, S. Sharma (CO2CRC), M. Verliac, A., Shujaat
• C. Jenkins, T. Dance, J. Ennis-King, M. Leahy (CO2CRC,
CSIRO), Y. Cinar (CO2CRC, UNSW), M. Asgharzadeh, A. Bona,
C. Dupuis, A. Dzunic, (CO2CRC, Curtin), P. Wisman, R. Li (ex-
CO2CR, Curtin), D. Sherlock (Chevron), T. Daley (LBNL)
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Established & supported under the Australian Government’s Cooperative Research Centres Program
CO2CRC Participants
Supporting Partners: The Global CCS Institute | The University of Queensland | Process Group | Lawrence Berkeley National Laboratory
Government of South Australia | CANSYD Australia | Charles Darwin University | Simon Fraser University