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The ability to predict lithology is one example of the potential of
multi-component technology to minimize reservoir lithology
uncertainty and to exploit and produce reserves faster and atlower cost.
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The North Sea field in this example is characterized by heterogeneous Paleocene
sandstone reservoirs. The shaling out of the sand makes exploitation and delineation
of the reservoirs very difficult. Analysis of log data from two wells, one with goodreservoir quality sand and a high net gross, and one with low net gross and only a
few sand lenses of reservoir quality, showed a strong correlation between good
reservoir and low Vp/Vs ratio. A seafloor multi-component survey was shot to better
define the shaling out of the sand.
Interpretation of instantaneous Vp/Vs sections can be used to predictchanges in reservoir quality to distinguish between clean and shaly sands.The figure above shows the instantaneous VP/Vs section for this example. The
reservoir interval is characterized by a low Vp/Vs value (denoted by orange) on
the left side. The Vp/Vs value increases (denoted by green) moving from left to
right. This interpretation demonstrates the degradation of the reservoir qualityseen in the well data.
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Seismic Attributes
We can use them to predict physical
properties away from well locations
But do we always know why they work?
If we dont, should we use them? How can we find out?
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Definitions
Seismic attribute: A derivative of a basic seismic measurement
(Brown, 1996)
A specific measurement of geometric,
kinematic, dynamic or statistical featuresderived from seismic data
(Chen and Sydney, 1997)
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Attribute study approach number 1: Horizon-based Extract physical property from wells (net sand, average porosity, etc.)
Extract attributes from seismic data at corresponding TWT (i.e., horizon slice) Look for correlations between seismic attributes and physical property at well
locations
Use correlations, if found, to produce a map of the physical property
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Attribute study approach number 2: Interval-based Extract physical property from wells (net sand, average porosity, etc.)
Extract attributes from seismic data in appropriate window Look for correlations between seismic attributes and physical property at well
locations
Use correlations, if found, to produce a map of the physical property
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Attribute study approach number 3: Volume-based Convert target log (porosity, Vsh, etc.) to time domain for all wells
Look for correlations between seismic attributes and physical property on asample-by-sample basis within a specific interval
Use correlations, if found, to produce a volume of the physical property (e.g.,
replacing the amplitude traces with predicted porosity logs)
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Conventional InterpretationConventional Interpretation
Pearson and Hart, 2004Pearson and Hart, 2004
Workflow for seismic attribute studies
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Attribute Studies Need careful traditional geoscience
interpretation Good well ties
Good seismic/log picks
Need good understanding of geology,geophysics, (geo)statistics
Ask the right questions Know when the answer is wrong
Vehicle for integration of geological, geophysical
and engineering data and concepts
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Attribute Studies Promoted/developed by software vendors
Few rigorous scientific papers Little documentation describing attributes
Methods (e.g., neural networks) that capturenon-linear relationships often give best results
Geologically, statistically
Caution: may find patterns where none exist!
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Attribute Studies Volume-based methods better than horizon- or
interval-based 3-D distribution of properties
Visualization provides insights
Need well data
Generally development settings
Use forward modeling to predict responses in
exploration/sparse well areas??
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Seismic data is converted to a layer-orientated model of the subsurface,
which is calibrated to the measured well log impedance. This clarifies
lithologic and stratigraphic identification
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