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BOREHOLE SEISMIC

3D VSP

Baker Atlas

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3D VSP

Tie of events to depth for 3-D seismic

High resolution near the well

Low cost for simultaneous acquisition with surface 3-D or for reverse VSP method

Extra studies - Anisotropy, AVO

Application to 4-D seismic studies

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3D VSP ACQUISITION

Rectangular grid - onshore

Circular or spiral marine acquisition

Detailed pre-survey modeling

Simultaneous acquisition with surface seismic

Reverse VSP

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3D VSP ACQUISITION

Rectangular gridBlackfoot survey

- Alberta, Canada

Circular gridOseberg field - North Sea

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receiver

source

sea bottom

Z depth

well head

borehole

circular wakaways

X East

Y North

Survey Geometry Example

circular walkaways

deviated well

five 3-components geophones

3D VSP ACQUISITION

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3D VSP PROCESSING

Standard procedures available in SEISLINK Special processing :

Statistical tool orientation

Statics application Wavefield separation Imaging 3D Visualization

Data volume considerations

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3-C rotation

source

receiver

V

H1

H2Downhole System Radial System

Z

R

T

3-COMPONENT ROTATION

rotate the data into a common coordinate system, theradial system

receivers are not gimbal mounted

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3-C ROTATIONEXAMPLES OF HODOGRAMS

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3D VSP PROCESSINGStatistical estimate of

tool orientation

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WAVEFIELD SEPARATION

Three common techniques

f-k (frequency-wavenumber) filtering

Medium filtering

Parametric Decomposition

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Circle16 Upwaves after three different wavefield separation techniques

After F-K filtering

time

time

time

After Median Filtering

After Parametric Decomposition

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WAVEFIELD SEPARATION

f-k filtering does not allow a good separation

Median filtering:

sharp imagebut

too small receiver array to do a good separation

Parametric Decomposition:

takes into account vertical and radial

components can separate overlapping events

but

image poorer in high frequencies

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Vertical Component Radial Component

time

time

time

time

WAVEFIELD SEPARATIONPARAMETRIC DECOMPOSITION

Circle16 - Comparison between real and syntheticdata for one gather.

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FINAL UPWAVES FOR IMAGING

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3D VSP IMAGING

Kirchhoff migration

VSP-CDP transformation

Splice VSP image into surface seismic

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Surface Seismic

Prestack Migration

Ellipse

S G

sourcegeophone

SURFACE SEISMIC AND VSPMIGRATION ELLIPSES

VSP migration ellipse

VSP geometry

Vertical and deviated well

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S

GS

G

OFFSET VSP MIGRATION ELLIPSE

Offset VSP geometry

Offset VSP

migration ellipse

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VSP MIGRATIONKIRCHHOFF SUMMATION

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984005_SEG98-7

TRAVEL TIME AND MIGRATION

RESPONSE

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VSP MIGRATIONSYNTHETIC EXAMPLE

Synthetic dataset input

to migrationMigrated data

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3D VSP MIGRATION

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3D VSP MIGRATIONSPLICED INTO SURFACE SEISMIC

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Offset VSP

Ray Trace 1 Geophone

Bent Trace Display

Stretched along Reflection Track

Western Atlas Logging Services VSP Training: 51

VSP-CDP TRANSFORMATIONTRACE BENT ALONG TRAJECTORY

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Bent TracesStretched Along Reflection Track

VSP - CDP TransformBinned at 25 Meter Interval

Depth(mete

rs)

Western Atlas Logging Services VSP Training: 52

VSP-CDP TRANSFORMATIONBINNING AND STACKING

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2D VSP-CDP TRANSFORMATION

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3D VSP-CDP TRANSFORMATIONSPLICED INTO SURFACE SEISMIC

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3D VISUALISATION

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3D VSP

REAL DATA EXAMPLES Oseberg

Blackfoot

Vinton Dome

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3D VSP - OSEBERG

38 circular walkaways 9900 shots deviated well

5-level receiver tool, 3-component receivers Non-gimballed phones Depth range : 2250 m - 2310 m Offset range : 200 m - 2500 m

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receiver

source

sea bottom

Z depth

well head

borehole

circular wakaways

X East

Y North

OSEBERG VSP GEOMETRY

Source points mapSurvey geometry schematicCircles centered above receivers

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3D MIGRATION CUBE LOCATION

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3D MIGRATION DATA CUBE

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SELECTED LINE LOCATION

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3D VSP MIGRATION

Depth-to-time converted

Spliced into surface seismic line

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3D SURFACE SEISMIC MIGRATIONPROCESSED BY ELF

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3D VSP-CDP TRANSFORMATION Depth-to-time converted

spliced into surface seismic line

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3D VSP - BLACKFOOT

12 source lines 431 shots vertical well

5-level receiver tool, 3-component receivers Offset range : 200 m - 2000 m

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SHOT POINT MAP

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TOTAL WAVEFIELD

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VSP-CDP mapping input data

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REFLECTION POINT MAP

RECTANGULAR BIN

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P WAVE TIME TRANSFORMRECTANGULAR BIN

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P-S WAVE RECTANGULAR BIN

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3D IMAGE VOLUME

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REFLECTION POINT MAP

POLAR BIN

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P WAVE TIME TRANSFORM

POLAR BIN

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P-S WAVE TRANSFORM

POLAR BIN

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SURFACE AND BOREHOLE

SEISMIC COMPARISON

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Zhangs Imaging Result 3D VSP Migration Result

University of Calgary (depth-to-time conversion)

47700

47500

47300

47100

46900

46700

47700

47500

47300

47100

46900

46700

600

800

1000

1200

1400

1600

TIME

3D - MIGRATION RESULT

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3D VSP - VINTON DOME

3-C velocity phones deployed in two wellbores Permanent (cemented) array of 62 levels at 50-ftspacing (950 to 4,000 ft)

Retrievable system array of 40 levels at 50-ft spacing(350 to 2,300 ft)

Data were recorded using an I/O RSR System IIacquisition system.

Recording of downhole data using RSR technologycould be interfaced with an MRX I/O System II cablesystem.

Minimal impact to surface seismic crew operations

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Piercement salt structure, multiple pay horizons

Over 140-MM barrels of oil produced

Spatial resolution of small (< 10 acre) compartmentscrucial for further development

3D VSP - VINTON DOMEOnshore Gulf Coast Oil Field

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Simultaneous acquisition of surface and downhole data - Key tosignificant cost savings and quick turnaround to useful image

Unique data quality and reproducibility - High signal-to-noise level(ambient) in cemented wellbore (over 80 dB) due to coupling of

cemented phones

Permanent downhole array is part of baseline survey for time-lapse(4-D) applications.

Downhole data aid in steep dip and salt flank imaging to augment

surface data.

All data acquired and controlled by the same recording instruments

3D VSP - VINTON DOMEBENEFITS

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3D VSP - VINTON DOMEBENEFITS

Improved interpretation due to early incorporation of accuratedownhole velocity model

Enhanced resolution of small reservoir compartments throughintegration of surface and downhole data

Improved spatial positioning due to velocity model accuracy

VSP-AVO reflector calibration and lithology upscaling

Salt flank imaging and near-salt heterogeneity imaging

Anisotropy parameter estimation near wellbore

Complimentary measurements of attributes for both data volumes;for example, statics, amplitudes, and velocities

Deploying the 3 C Array

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Deploying the 3-C Array

3D Postplot Showing Location of

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XXX

+++ Receivers

Sources

Instrumented Well

Source Points

C

B

A

0 6000 ft

3D Postplot Showing Location of

Instrumented Wells

G l i C S ti

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Geologic Cross SectionG-23ABC

1000

0

2000

3000

4000

5000

6000

7000

8000

9000

10000

11000

TVDss(f

t)

3-D Migrated Profile Through Sources

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g g

A, B, C, and an Instrumented Well

0

1000

2000

3000

Salt

G-23

G-23ABC

Time(ms

)

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Source Statics from Surface Seismic

Source Record Along a Radial Profile Through One of the

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400

0

800

1200

1600

2000

400

0

800

1200

1600

2000

Radial Component Tangential Component Vertical Component

Source A - Offset 1,179 ft.

Time(ms)


Instrumented Wells - Depths from 950 ft. to 4,000 ft.


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400

0

800

1200

1600

2000

400

0

800

1200

1600

2000


Time(ms)

Source B - Offset 2,582 ft.




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Source C - Offset 6 232 ft

400

0

800

1200

1600

2000

400

0

800

1200

1600

2000


Time(ms)

g g


tema 10_3d vsp

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