Increase certainty in complex channel sand reservoir
Petronas planned to drill a horizontal well in Malaysia in a channel
sand formation with uncertain fluid contacts, lateral sand distribution, and
formation dips. To undertake this structurally and stratigraphically complex
project, Petronas needed more information about the reservoir to determine the
optimal well placement location to target a reservoir sand with expected
production of 900 bbl/d.
Map reservoir to delineate subsurface bedding and fluid contact
details
Schlumberger recommended using the GeoSphere reservoir
mapping-while-drilling service to increase certainty by mapping the channel
sand reservoir in real time more than 100 ft [30 m] from the wellbore. Using
deep, directional electromagnetic measurements, the GeoSphere service would
help Petronas refine the seismic model in real time, making the reservoir less
risky to develop.
Landed well and revealed previously undetected reservoir sand
Using the GeoSphere service to fully map the channel sand reservoir,
Petronas effectively landed the well on target to develop the reservoir sand,
which had an expected production of 900 bbl/d. The mapping also led to the
discovery of a second hydrocarbon-bearing sand with production of 1,700 bbl/d.
Petronas drilled a sidetrack to develop the newly-discovered channel sand. As a
result, the operator increased initial anticipated recovery rate by 88%, as
compared to 900 bbl/d. Additionally, Petronas plans to produce the original
target at an estimated 900 bbl/d as dictated by production in the larger
channel sand.
Before entering the reservoir, the GeoSphere service mapped the top of
the reservoir at 45-ft [14-m] true vertical thickness (TVT). The service mapped
the top, base, and dip at distances up to 82 ft [25 m] from the wellbore. Using
that information, Petronas was able to steer the lateral within the sweet spot
for 1,968-ft [600-m] MD, complement seismic information, and enhance field
development plans.
