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- E-ISSN: 1365-2478
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Well tie, fluid substitution and AVO modelling: a North Sea example[Link]
- Source: Geophysical Prospecting, Volume 46, Issue 3, Apr 0198, p. 323 - 346
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- 04 Jan 2002
Abstract
Accurate well ties are essential to practical seismic lithological interpretation. As long as the geology in the vicinity of the reservoir is not unduly complex, the main factors controlling this accuracy are the processing of the seismic data and the construction of the seismic model from well logs. This case study illustrates how seismic data processing to a near‐offset stack, quality control of logs and petrophysical modelling improved a well tie at an oil reservoir. We demonstrate the application of a predictive petrophysical model in the preparation and integration of the logs before building the seismic model and we quantify our improvements in well‐tie accuracy. The data for the study consisted of seismic field data from a 3D sail line through a well in a North Sea oilfield and a suite of standard logs at the well. A swathe of fully processed 3D data through the well was available for comparison. The well tie in the shallow section from first‐pass seismic data processing and a routinely edited sonic log was excellent. The tie in a deeper interval containing the reservoir was less satisfactory: the phase errors within the bandwidth of the seismic wavelet were of the order of 20°, which we consider too large for subsequent transformation of the data to seismic impedance. Reprocessing the seismic data and revision of the well‐log model reduced these phase errors to less than 10° and improved the consistency of the deep and shallow well ties. The reprocessing included densely picked iterative velocity analysis, prestack migration, beam‐forming multiple attenuation, stacking the near‐offset traces and demigration and remigration of the near‐offset data. The petrophysical model was used to monitor and, where necessary, replace the P‐wave sonic log with predictions consistent with other logs and to correct the sonic log for mud‐filtrate invasion in the hydrocarbon‐bearing sand. This editing and correction of the P‐wave transit times improved the normal‐incidence well tie significantly. The recordings from a monopole source severely underestimated the S‐wave transit times in soft shale formations, including the reservoir seal, where the S‐wave velocity was lower than the P‐wave velocity in the drilling mud. The petrophysical model predicted an S‐wave log that matched the valid recordings and interpolated between them. The subsequent seismic modelling from the predicted S‐wave log produced a class II AVO anomaly seen on the CDP gathers around the well.