Expedite processing and interpretation up to 10× faster than conventional methods.
An operator needed to determine porosity from sonic slowness and use wellbore images along with surface seismic interpretation to identify structural features. Identification of fracture intervals is normally done with borehole imaging data alone; however, the operator needed a solution that would provide a deeper depth of investigation into the reservoir and determine the extent of the fractured zones.
Both standard and slim dipole sonic logging tools were deployed to obtain images along the lateral. The slim dipole sonic image, acquired on through-the-bit logging conveyance, was similar to the image obtained from the standard sonic tool, and both images captured the major boundaries along the well track.
Schlumberger then provided the 3D farfield sonic service to identify fractures tens of feet away from the borehole region. Complementing traditional sonic imaging techniques and borehole imaging logging, the automated 3D far-field sonic service rapidly provides the true dip and azimuth of fractures and formation layers located well beyond the reach of standard sonic logging. The service determines connectivity for open fractures and identifies subseismic structural features, tracing them from the borehole wall through the near-field and far-field reservoir. Using the 3D far-field sonic service, data was recorded along a high-angle interval with a borehole diameter of 57/8 in and well deviation ranging between 84° and 90°.
Using azimuthal sensors from the complementary 3D far-field sonic service detected the presence of naturally fractured intervals. The orientation (dip and azimuth) of these features was consistent with the borehole image and provided a deeper depth of investigation into the reservoir, seeing fractures of up to 60 ft away from the borehole.