Ocean bottom seismic in the oseberg south area j daniels
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Transcript of Ocean bottom seismic in the oseberg south area j daniels
1 - Classification: Internal 2010-06-11
Ocean Bottom Seismic in the Oseberg South area
John Dangerfield, Jim Daniels, Per Riste, Mari Skaug and Vibeke Haugen
2 - Classification: Internal 2010-06-11
ΩC
GC
BJ
K
GØ
δ Oseberg Sør
R
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Oseberg Sør
Many areas of bad data…But we have great production wells
C J
4 - Classification: Internal 2010-06-11
Series of down stepping fault blocks
Thin reservoirs – often little or no seismic expression
Increasing erosion of Brent to east
Omega
G-Central Tune
BCUDraupn
e/
Heather
UTarbertMT2
MT1LT
UNessLNess
Coal
Channel Sandston
e
J-StructureC-structureG-East
BCUDraupn
e/
Heather
UTarbertMT2
UNess
Coal
Channel Sandston
e
Geological cross section through Oseberg Sør
West East
5 - Classification: Internal 2010-06-11 C-structure F-12, F12A and F-12 B.
F-12 B: Success!
30/9-6 Exploration well
1 km
F-12: Water wet
F-12 A: No sand
Production profile F-12 B
0,
500,
1000,
1500,
2000,
jul-04 jan-05 aug-05 feb-06 sep-06
Sm
3/d
Actual
Predicted
3 wells, payback time 80 days
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1 km
Dolomitised Oligocene sands
Poor image
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50 meters away
Poor image
50 m away
1 km
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Sonic logs
1500 5000 m/s
30/9-6 30/9-13S
1500 5000 m/s
Thin dolomitised sands
Destroy the seismic image
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Top Shetland beneath an Oligocene sand
Effect of dolomitised sands on the Seismic gathers
10 - Classification: Internal 2010-06-11Acquired N-S Acquired E-W
Dolomite sand Dolomite sand
The same seismic line…
Different imageDifferent image
30/9-6 30/9-6
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Shots Receivers
Effects of shooting orientation
Reflection point
Reflection point
Dolomite sands
Dolomite sands
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Seismic
5000 m/s sand
Sand model generated from surface seismic
2000 m/s overburden
Model
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Top Shetland model (no sand)
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Overburden sands
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Magnified model
Apparent faults Pull-up Low amplitude
Top Shetland
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Real gathers
Model gathers
The model looks like the real data
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(11)
(3)
(5)
(7)
(1)Number of Azimuths
FOLD
25
75
125
175
225
Model stack of Top Shetland with different numbers of azimuths
Conclusion: Minimum 7 well spaced azimuths
required
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What is OBC?Seismic receivers are on the seafloor
Records both P-wave (compression) and S-wave (shear)
We shoot crossline to get multiazimuth coverage
Receivers
Shot points
from PGS
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Top Reservoir
C-structure
30/9-6
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OBC gather
Single gather
2.5 kmTop Reservoir
C-structure
With dolomite
sands
Multi-azimuth gives much better
illumination
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OLD DATA2005 OBC DATA
Dolomite sands
C-structure
Reservoir section
C-structure
30/9-6
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Marine data, reservoir section
OBC data, reservoir section
Base Cretaceous
Top Lower Tarbert
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2005 Model – Streamer 2007 Model – OBC
C – STRUCTURE (same interpreter)
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C-structure OBC 2005 (25 Km2)
J-structure OBC 2008 (76 km2)
OBC surveys Oseberg Sør
OBC surveys potential base 4D OBC surveys
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Streamer
NH9802
Six cable marine acquisition
Time migration
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2008 OBC
ST0823
OBC acquisition
Fastrack PreSDM migration
Processed in 6 weeks
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2008 OBC Streamer
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2008 OBC Streamer
Oseberg Area Unit RC meeting 27.05.2009
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OBC NS and EW surveys Streamer 2004
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2006 Model – Streamer data 2009 Model – OBC data
J – STRUCTURE (same interpreter)
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Gas sand
Oil sand
Water sand?
Shaley sand
Shale
Carbonate
Inversion resultsSuggest fluvial features
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Gas sand
Oil sand
Water sand?
Shaley sand
Shale
Carbonate
Inversion resultsSuggest fluvial features
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Gas sand
Oil sand
Water sand?
Shaley sand
Shale
Carbonate
Inversion resultsSuggest fluvial features
34 - Classification: Internal 2010-06-11
Gas sand
Oil sand
Water sand?
Shaley sand
Shale
Carbonate
Inversion resultsSuggest fluvial features
35 - Classification: Internal 2010-06-11
Gas sand
Oil sand
Water sand?
Shaley sand
Shale
Carbonate
Inversion resultsSuggest fluvial features
36 - Classification: Internal 2010-06-11
Gas sand
Oil sand
Water sand?
Shaley sand
Shale
Carbonate
Inversion resultsSuggest fluvial features
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Gas sand
Oil sand
Water sand?
Shaley sand
Shale
Carbonate
Inversion resultsSuggest fluvial features
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Why OBC?
• Multiazimuth illumination:
− Better structural image, better horizon identification, better investment decisions
• Inversion is better: low frequencies, complete far offsets, S-wave data.
− Possibility to identify sands and fluids
• Monitoring production and injection effects:
− Accurate 4D repeat position, plus PS data, no platform hole
• Can be cheaper!
− Sparser acquisition, less weather downtime, no 3D and 4D infill,
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what we aspire to:• Accurate maps for reservoir modelling
• Accurate prognoses for planned wells (including drilling hazards)
• Accurate lithology and fluid prediction from seismic
• Production effects from 4D seismic
With a poor seismic image none of these goals is achievable
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Seismic budget
Planning
Acquisition
Processing
Interpretation
Depth
Rock physics
Lithologies
Fluids
Production effects
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Ocean Bottom Seismic in the Oseberg South areaJohn Dangerfield, Jim Daniels, Per Riste, Mari Skaug and Vibeke HaugenPresented by Dr Jim Daniels
Principal Geophysicist
[email protected] tel: +47 48151755
www.statoil.com
Thankyou
The authors wish to thank the following partners for permission to publish this data:
•ConocoPhillips Skandinavia AS
•Petoro AS
•Total E&P Norge
•ExxonMobil Exploration and Production Norge AS.
The conclusions drawn are those of the authors alone.
42 - Classification: Internal 2010-06-11Classification: Internal 2010-05-03