Characterize formation porosity and lithology while drilling with azimuthal density measurements (ADN).
An operator drilling in the Dutch sector of the North Sea wanted to access oil from additional lower-permeability zones to increase production. The reservoir is divided into four zones— A, B, C, and D—consisting of Lower Cretaceous prograding shoreface deposits. With most of the oil production coming from the highly permeable A zone, the operator planned to drill a horizontal well to reach the lower-permeability B and C zones, with the option to fracture stimulate.
Reservoir challenges included seismic uncertainty of ±5-m TVD, mud losses, unexpected faults, and formation dip uncertainty. Also, if the well was drilled outside the target production zones, there was potential for water production and poor stimulation results due to deviations in trajectory.
Schlumberger petrotechnical and drilling experts collaborated with the operator to determine the optimal well placement, stimulation, and completion strategies based on the specific drilling challenges. The adnVISION azimuthal density neutron service was recommended for use in conjunction with the ImPulse integrated MWD platform to provide critical real-time data for formation evaluation while drilling the horizontal section for accurate well-to-well correlation. The PowerDrive RSS was also recommended to ensure directional control of the well path.
For more informed decision making while drilling, the petrotechnical experts created a workflow for real-time interpretation that integrated the Petrel E&P software platform and the eXpandBG near-wellbore to reservoir-scale modeling software. The eXpandBG software provides geological interpretation of borehole images and dip data to perform single-well and multiwell interpretation, 3D structural modeling, and well placement services for improving drilling and reservoir development decisions.
The real-time interpretation-guided geosteering enabled the operator to successfully land the deviated well in the target zones. A 372-m interval was placed below the top of the lower C zone in a section suitable for fracture stimulation, and 835 m of the trajectory was placed within the B and upper C zones. The last 200-m section was placed parallel to the formation with the bit 3-m TVD below the barrier between the A and B sand zones. This was achieved through accurate geological interpretation of the formation dip while drilling to resolve uncertainty in the seismic data.
This operation was the first remote well placement job for the operator. Expertise, teamwork, and the optimal combination of technologies and services enabled the operator to achieve its objectives without failures and without the need for sidetracking the well.
Challenge: Account for uncertainty in formation dip and other challenges in placing a highly deviated well in the target zones of a reservoir.