© 2009 Paulsson, Inc. (PI)

3D Images from a Multi Well 3D VSPsurvey

Paulsson, Inc. (PI) Brea, CA

© 2009 Paulsson, Inc. (PI)

Improved reservoir management by generating seismic images in “non seismic” areas

Increase recoverable reserves by guiding infill or side track drilling Reduced drilling cost from better targeting Provide effective monitoring of reservoirs for changes due to

production or injection Obtain a true calibrated depth image along the array 3D borehole seismic imaging is the highest resolution 3D imaging

technology in the oil and gas industry today.

Business Reasons for 3D Borehole Seismic Surveys

© 2009 Paulsson, Inc. (PI)

1

Final Edison Field Shot Map with well locations

8

1

2

3

4

5 67

3D VSP Shot MapShot map of 5,200 shots into 8 wells – 1,040,000 traces.

14 kft

12 kft

© 2009 Paulsson, Inc. (PI)

The Client’s Reservoir Issues

Surface seismic does not work in the Edison Field Available data was sparse, old vintage, and 2D Noisy environment (lots of pumping wells) Low Signal/Noise and Low frequency surface data

(under 25 Hz) Highly attenuating near surface with a P wave velocity of

less than 1,500 ft/s Complex geology – requiring at least 75 Hz to image Shallow primary targets (2,000 ft) Secondary deeper targets (5,000 ft)

© 2009 Paulsson, Inc. (PI)

Record a 3D VSP in several wells 40 levels/well (would use 80-160 per well today) ~1,000 Shots per well Vibroseis source sweeping to 150 Hz

Integrated service – from acquisition to image In field processing to assure consistent data quality Image produced with 25 ft bins sampled 5ft vertically

The Proposed Solution

© 2009 Paulsson, Inc. (PI)

Seismic source: A single surface 43,000 lb. vibrator

Source Line spacing: 250 ft, Source spacing: 100 ft

Sweep parameters: sum of four 12 sec. 10 - 150 Hz sweeps

Number of shot points: 5,200

5,200 Shots used for Massive 3D VSP migration within 3,600 ft radius of the receiver wells

Reservoir depth (ft): 1,500 - 3,000

Receiver well depths: TD (ft): 2,000 - 3,000

Well information: Casing: 7”

Receiver array depth: 0 - 2,500 ft, 2 x 40 levels, dz = 50 ft

Basic Survey information

© 2009 Paulsson, Inc. (PI)

Massive 3D VSP Data

© 2009 Paulsson, Inc. (PI)

Depth (ft)

Inte

rval

Vel

ocity

(ft/s

ec)

Multi Well 3D VSP: Interval Velocities from log and VSP

Blue: Well logPurple: VSP

Non Surface Seismic Data Area

© 2009 Paulsson, Inc. (PI)

Vaquero Energy – Edison 3D VSPDeconvolved Upgoing Wavefield & Spectra

© 2009 Paulsson, Inc. (PI)

Vaquero Energy – Edison 3D VSPFlattened Downgoing Wavefield Spectra

© 2009 Paulsson, Inc. (PI)

Vaquero Energy – Edison 3D VSPFlattened Downgoing Deconvolved Wavefield Spectra

© 2009 Paulsson, Inc. (PI)

Massive 3D VSP 3D Images

© 2009 Paulsson, Inc. (PI)

Vaquero Energy – Edison 3D VSP3D Velocity Image from a Massive 3D VSP

© 2009 Paulsson, Inc. (PI)

Vaquero Energy – Edison 3D VSP3D Velocity Image from a Massive 3D VSP

© 2009 Paulsson, Inc. (PI)

3D Image from a Multi well Massive 3D VSP

© 2009 Paulsson, Inc. (PI)

2D Slice

Vaquero Energy – Edison 3D VSP

© 2009 Paulsson, Inc. (PI)

Vaquero Energy – Edison 3D VSP2D Slice

© 2009 Paulsson, Inc. (PI)

Vaquero Energy – Edison 3D VSP3D Image from a Massive 3D VSP

© 2009 Paulsson, Inc. (PI)

Vaquero Energy – Edison 3D VSP

3D Image from a Massive 3D VSP

© 2009 Paulsson, Inc. (PI)

A 3D Image of the Edison Oil Reservoir

© 2009 Paulsson, Inc. (PI)

Drilling a deviated well in the Edison Field, California

Using a 3D image from aMassive 3D VSP

© 2009 Paulsson, Inc. (PI)

Oil Sands in DS #2-X doesn’t make it over to the DS #3

Vaquero Energy – Edison 3D VSP

New Interpretation based on 3D image

© 2009 Paulsson, Inc. (PI)

Oil Sands in DS #2-X well doesn’t make it over to the DS #3 well.

Vaquero Energy – Edison 3D VSP

New Interpretation based on 3D image New deviated well

Fault

Drilling result: The new well encountered 300 ft of oil and became the biggest producer in the field

© 2009 Paulsson, Inc. (PI)

Initial success recording excellent data expanded the survey from 2 to 8 wells

Data exceeding 120 Hz in the final image Excellent correlation with extensive existing well data Well drilled on the 3D VSP image The well drilled was initially the most productive well in

field! Cost of the full 8 well survey and the drilling of 1 new well

was recovered from just 4 months of production (at $30/bbl)

Results

© 2009 Paulsson, Inc. (PI)

The data shown in this presentation shows that the 3D VSP method is capable of imaging complex geology using data simultaneously recorded in several wells at the same time.

A 3D View of the data is essential in understanding the Image

130 Hz high quality VSP data was recorded in an area where surface seismic produced very little useful information to aid infill drilling decisions. The surface data was 25 Hz and yielded very low S/N ratio.

Edison 3D VSP - Summary

© 2009 Paulsson, Inc. (PI)

End of Presentation