Reservoir testing and sampling in unconsolidated sands presents many challenges. Repsol needed to collect representative samples in reservoirs with unconfined compressive strength (UCS) as low as 100 psi; test these reservoirs to ensure sufficient productivity potential; verify oil viscosities along depths in three, large-stacked sands; and assess reservoir vertical connectivity.
SLB recommended DTT using the Ora intelligent wireline formation testing platform. Its architecture features advanced metrology, tenfold-larger flow rate capabilities compared with conventional technology, and long flow times that help ensure safe well control while circulating produced hydrocarbons during the test. To visualize and design the test, a three-step simulation was conducted.
In other sands with similar flow capacity, SLB recommended scanning and sampling fluids to inspect viscous grading. A combination of probes with third-party mesh filters mounted on the inlets was proposed to avoid sand production while mitigating plugging risks.
Repsol safely conducted DTT, collected representative samples, and scanned fluid properties at four additional depths. During DTT, circulating active hydrocarbons avoided the need to perform a long test and flow to a barge for disposal of fluids at surface. The platform provided horizontal permeability (kh), vertical permeability (kv), and skin results to understand reservoir productivity, while downhole fluid analysis complemented with downhole constant composition experiments provided all fluid inputs required to model the fluids.
The results were evaluated analytically and numerically using Repsol’s static model, which was populated with acquired Ora platform fluid properties. This provided an understanding of the viscosity profiles seen in the stacked reservoir sands, productivity forecasts of the DTT layer, and minimum connected hydrocarbons in place.
