scholarly journals Time-Lapse Vertical Seismic Profiling (VSP) for CO2 Storage in a Depleted Oil Field in Northern Michigan

2021 ◽  
Author(s):  
Mark Kelley ◽  
Autumn Haagsma ◽  
Neeraj Gupta
Keyword(s):  
Co2 Storage ◽  
Time Lapse ◽  
Oil Field ◽  
Seismic Profiling ◽  
Vertical Seismic Profiling ◽  
Northern Michigan

scholarly journals InSAR Monitoring to Evaluate Surface Changes with CO2 Storage in a Depleted Oil Field in Northern Michigan

2020 ◽  
Author(s):  
Matthew Place ◽  
◽  
Marie-Josée Banwell ◽  
Giacomo Falorni ◽  
Neeraj Gupta
Keyword(s):  
Co2 Storage ◽  
Oil Field ◽  
Northern Michigan ◽  
Surface Changes

Comparison of vertical seismic profiling techniques

Geophysics ◽  
1993 ◽  
Vol 58 (1) ◽  
pp. 134-140 ◽  
Author(s):  
Linda J. Zimmerman ◽  
Sen T. Chen
Keyword(s):  
Three Dimensional ◽  
Seismic Profile ◽  
Oil Field ◽  
Seismic Profiles ◽  
Severe Problem ◽  
Seismic Profiling ◽  
Vertical Seismic Profiling ◽  
Imaging Characteristics ◽  
Profiling Techniques ◽  
Tube Wave

To study the imaging characteristics of various vertical seismic profiling techniques, two vertical seismic profiles (VSP) and a reversed vertical seismic profile (RVSP), where source and receiver positions are interchanged, were collected in the Loudon Oil Field in Illinois. Both VSPs were collected using a line of dynamite charges on the surface as sources. One was collected with geophones and the other with hydrophones as downhole receivers. The RVSP was collected by detonating 25 gram explosive charges in a well and detecting the seismic response with geophones at the surface. Three subsurface images (VSP with geophones, VSP with hydrophones, and RVSP) were produced using VSP-CDP transforms. For comparison, a surface seismic profile was collected along the same line with dynamite sources and vertical geophone receivers. The RVSP and hydrophone VSP stacked sections both produced higher frequency images at shallower depths than did the geophone VSP stacked section. However, the lower frequency geophone VSP stacked section produced an interpretable subsurface image at much greater depths than either the RVSP or the hydrophone VSP sections. The differences are due in part to the more powerful surface sources that were used for the VSPs than the downhole sources used for the RVSP. Furthermore, tube‐wave noise was a more severe problem for both the RVSP and the hydrophone VSP than for the geophone VSP. The results of this experiment demonstrate that if tube‐wave noise could be suppressed, hydrophone VSPs would provide attractive alternatives to geophone VSPs, because it is much easier and cheaper to deploy multilevel hydrophones downhole than geophones. Also, if a high‐powered, nondestructive source is developed, RVSP could be a practical alternative to VSP since one can easily lay out numerous receivers on the surface to record multioffset or three‐dimensional (3-D) VSP data.

scholarly journals InSAR Monitoring to Evaluate Surface Changes with CO2 Storage in a Depleted Oil Field in Northern Michigan

2021 ◽  
Author(s):  
Matt Place ◽  
Neeraj Gupta ◽  
Giacomo Falorni ◽  
Marie-Josée Banwell
Keyword(s):  
Co2 Storage ◽  
Oil Field ◽  
Northern Michigan ◽  
Surface Changes

scholarly journals Case History: Using time-lapse vertical seismic profiling data to constrain velocity-saturation relations: the Frio brine pilot CO2injection

2016 ◽  
Vol 64 (4) ◽  
pp. 987-1000 ◽  
Author(s):  
Mohammed Al Hosni ◽  
Eva Caspari ◽  
Roman Pevzner ◽  
Thomas M. Daley ◽  
Boris Gurevich
Keyword(s):  
Case History ◽  
Time Lapse ◽  
Seismic Profiling ◽  
Velocity Saturation ◽  
Vertical Seismic Profiling

Modeling the seismic response of individual hydraulic fracturing stages observed in a time-lapse distributed acoustic sensing vertical seismic profiling survey

Geophysics ◽  
2020 ◽  
Vol 85 (4) ◽  
pp. T225-T235
Author(s):  
Gary Binder ◽  
Aleksei Titov ◽  
Youfang Liu ◽  
James Simmons ◽  
Ali Tura ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Decay Time ◽  
Time Lapse ◽  
S Wave ◽  
Acoustic Sensing ◽  
Seismic Profiling ◽  
Vertical Seismic Profiling ◽  
Effective Medium Model ◽  
Surface Time ◽  
Distributed Acoustic Sensing

In 2017, distributed acoustic sensing (DAS) technology was deployed in a horizontal well to conduct a vertical seismic profiling survey before and after each of 78 hydraulic fracturing stages. From two vibroseis source locations at the surface, time shifts of P- and S-waves were observed but decayed over days. Some stages also showed waves scattered off the stimulated rock volume. We have used 2D finite difference elastic wavefield modeling to understand these observations and connect them to underlying properties of the stimulated rock. We have developed an effective medium model of vertical fractures that close exponentially with time as fluid leaks off into the formation can match the distribution of P- and S-wave time shifts along the well. This has enabled estimates of the height, normal and tangential fracture compliance values, and decay time of the stimulated rock volume. Additionally, the kinematics of scattered waves observed in the data have been found to be consistent with PS conversion across the stimulated rock volume from an individual stage. With higher quality DAS data, stage-by-stage inversion for height, fracture compliance, and decay time attributes may be possible for characterizing variations in the effectiveness of hydraulic fracturing.

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