Many
oilfield development projects require artificial lift systems,
i.e., methods to enhance well fluid production that are needed when
the reservoir pressure is too low to allow for the produced fluid
to reach the surface. Such an approach is of particular interest for
mature oilfields (such as those in the Middle East and North Africa)
and for many of the upcoming deepwater and ultra-deepwater fields
under development around the world. Artificial lifting can be achieved
by gas lifting or through a pump installed into the well. For subsea
downhole applications, a progressive cavity pump (PCP) or (centrifugal)
electrical submersible pump (ESP) is employed. ESP systems are having,
in particular, wide spreading, essentially as a result of the good
efficiencies and high rates and depth. In search of means for maximizing
the productivity of each well that sometimes leads to looking for
producing the maximum in the shortest possible time, these pumps are
seen as a sort of panacea. In this work, a dangerous possible drawback
is highlighted: if the system is not correctly designed, it can result
in a perfect tool to generate very viscous asphaltene-stabilized emulsions.
The behavior of the system is described along with the impacts generated
on the pump. A verification criterion is proposed to be used during
ESP design and selection of correct working conditions, and a case
study is presented.