New seismic and exploration data was loaded into PetroMod software to
help examine the block's stratigraphic and geochemical composition, and to
investigate the petroleum system elements. Next, 2D modeling was undertaken to
incorporate structural detail into the study and model migration and
Subsequent 3D modeling improved the resolution and extended the model to
over 1,700 km2. This allowed for an improved assessment by relating the timing
of hydrocarbon generation, migration, and accumulation to trap formation,
through simulation of all the petroleum system elements: charge, reservoir,
seal, and trap. Total accumulations were then calculated to show remaining
potential zones for prospect ranking.
The team discovered that only source rocks in the deepest part of the
Komombo area Block 2 basin were already in the oil window during the Early
Cretaceous, presenting 50% transformation ratio (TR) at ~80Ma. Source rocks in
the Abu-Ballas formation represented <20% TR, and the Taref coal and Dakhla
formations are <1% at present day.
New development lease secured
The four main reservoirs in the study showed good potential for
hydrocarbon reservoir formation, fed mainly from Komombo B source rock, with
accumulation represented in structure trap system of anticlines and faults, and
a stratigraphic trap system of onlap and facies boundaries.
The petroleum system modeling results were central to the Dana Gas and
Sea Dragon team's new drilling strategy, and were integrated into its
exploration and prospect evaluation workflows. Successful exploratory wells
were then drilled in the area and were pivotal in the team securing a new