20b_ seismic intepretation
TRANSCRIPT
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8/18/2019 20b_ Seismic Intepretation
1/6
REU
Pittsburgh, PA
9/24/21
Tim
Carr
West Vir gin ia University
Understanding Seismic Data
Resolution (Vertical and Horizontal)
Two way time (TWT)
Time to Depth conversion
Interpretation of Reflectors
Creating a consistent interpretation
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ExxonMobil
Increase in Impedance Decrease in Impedance
Able to resolve boundaries of beds a few meters thick
1 meter
3 ExxonMobil
CompressionRarefaction
A A = Amplitude
λ = Wavelength
length, ft or m
λ
P = Periodtime
Period = Time for the waveform
to travel 1 wavelength
Dp = PulseDuration
time
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ExxonMobil
10 m
Predominantly
Shale
Predominantly
Shale
Predominantly
Sand
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8/18/2019 20b_ Seismic Intepretation
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REU
Pittsburgh, PA
9/24/21
Tim
Carr
ExxonMobil
Although seismic data can not image small‐scale stratal units, it can image mid‐ to large
‐scale
units
Parasequences
Bed Sets
Parasequence Sets
Sequences
Beds
Lamina Sets
Lamina
Sequence Sets
The big advantage of seismic data is areal coverage
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There are many reflectors on a seismic section. Major changes in properties
usually
produce
strong,
continuous reflectors as shown by the arrow.
A seismic reflector is a boundary between beds with different properties. There may be a change
of
lithology
or
fluid
fill
from
Bed
1
to
Bed 2. These property changes cause some sound waves to be reflected towards the surface.
Bed 1
Bed 2
lower velocity
higher velocity
energy
source
signal
receiver
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ExxonMobil
Shale
Sand
Velocity = 2000 m/sDensity = 1.7 gm/cc
Velocity = 2400 m/sDensity = 1.8 gm/cc
ReflectionCoefficient
= =I below – I above
I below + I above=
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Shale
Sand
Velocity = 2000 m/sDensity = 1.7 gm/ccI = 2000 * 1.7 = 3400
Velocity = 2400 m/sDensity = 1.8 gm/ccI = 2400 * 1.8 = 4320
ReflectionCoefficient
=4320 - 3400
4300 + 3400=
I below – I above
I below + I above= 0.119
Of the incident energy, 12% is reflected, 88% is transmitted
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Shale
Carbonate
Velocity = 2000 m/sDensity = 1.7 gm/cc
Velocity = 2600 m/s
Density = 2.1 gm/cc
ReflectionCoefficient
= =I below – I above
I below + I above=
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Shale
Carbonate
Velocity = 2000 m/sDensity = 1.7 gm/cc
I = 2000 * 1.7 = 3400
Velocity = 2600 m/s
Density = 2.1 gm/ccI = 2600 * 2.1 = 5460
ReflectionCoefficient
=5460 - 3400
5460 + 3400=
I below – I above
I below + I above= 0.232
Of the incident energy, 23% is reflected, 77% is transmitted
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8/18/2019 20b_ Seismic Intepretation
3/6
REU
Pittsburgh, PA
9/24/21
Tim
Carr
0.25 seconds
Two way time (TWT)
indicates the
time
required for the seismic wave to travel from a source to some point below the surface and back up to a receiver.
In this example the TWT is 0.5 seconds.
0.25 seconds
0
0.5
TWT
s e c o n d s
surface
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0.58 sec
m
1865
926
288
926 m
Two way time (TWT) does not equate directly to depth
Depth of a specific reflector can be determined using wells
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ExxonMobil
Seismic Shot
Borehole
Geophone
D e p t h
Check shots measure
the vertical one‐ way
time from surface to
various depths within
the well
Used to calibrate well
depths and times from a
sonic log
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Interval velocity
Integrated
Sonic log
ExxonMobil
Use the sonic and density logs to compute an impedance ‘log’
Veloc it y Den si ty Imp ed an ce
=x
Shale
Sand
Shale
Sand
Shale
LithologyReflection
Coefficients
Calculate the reflection coefficients
*
Wavelet
Convolve our pulse with the RC series to get individual wavelets
Each wavelet’s amplitude is proportional to the RC
Synthetic
Sum the individual wavelets to get the synthetic seismic trace
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Log data Calculated
ExxonMobil
Compare well data to seismic data
Relate horizon
tops
in
a
well with specific reflections
Synthetic Trace
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8/18/2019 20b_ Seismic Intepretation
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REU
Pittsburgh, PA
9/24/21
Tim
Carr
Average velocity map of reflector‐1 25 Depth map of reflector‐1 26
ExxonMobil
Structural Interpretation Faults & Folds
Subsidence & Uplift
Structural Trends
Structural Features
Stratigraphic Interpretation Unconformities
Stratal Packages
Environments / Facies / Lithologies
Ages
Using all available data (wells, seismic, outcrop, regional studies, gravity, magnetics, etc.) build a framework of present‐day structure and stratigraphy
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Determine the local geology from the subsurface images
Map faults and other structural features
Map unconformities and other major stratal surfaces
Interpret depositional environments
Infer lithofacies from reflection patterns & velocities
Predict
ages
of
stratal
units
Examine elements of the HC systems
Mitchum et al., 1977
AAPG©1977 reprinted wit h permission of the AAPGwhose permission is required for further use.
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Relate features seen in seismic to stratigraphic or structural processes
Interpretation
Seismic Image of Ancient Reef in Alberta [400 million years old]
29 Uses computer technology to interpret seismic data
Interpretation
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8/18/2019 20b_ Seismic Intepretation
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REU
Pittsburgh, PA
9/24/21
Tim
Carr
Salt domes pierce strata
and creating favorable
trapping geometry in the
Ekofisk Fm.
8km
Fancier stuff: Ant tracking of salt domes for fracture detection
Variance Attribute‐ Trace to trace variability in 3D seismic block
Patchawarra Surface at 1.752 sec
4 Km
Uses high tech visualization to interpret seismic data
Interpretation
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Seismic ReflectorsDifference in Impedance of UnitsImpedance Function of Density and Velocity
Resolution Limited to 10’s of meters Areal Coverage
Seismic versus Depth Well to Seismic Ties Velocity ModelConvert TWT to Depth
Seismic Interpretation Provides Earth Image
Structure and
Stratigraphy
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