American Oil and Gas Reporter - June 2015 - 79

atures generated by gas slugs, while particle swirl suppression ribs in the diffuser
provide abrasion resistance and reduce
abrasion buildup.
In a second application in Oklahoma
for another operator, using the tightradius ESP system made it possible to
produce through a high-degree bend that
previously had limited artificial lift options
and hydrocarbon production.
The challenge in this newly drilled
well was a 16 degrees/100 foot build
rate that was beyond the pass-through
capability of a traditional ESP, limiting
both artificial lift options and production
performance. With the tight-radius system,
the ESP passed through the deviation
and was installed successfully. The operator avoided the cost of a redrill or
sidetrack, and the well performed as expected. In addition, ESP installation time
was cut in half.

Integrated Production Solution
Implementing technology in a piecemeal fashion can drive up lifting costs
and introduce long-term inefficiencies.
The tight-radius ESP was developed as a
key component in a flexible, integrated
production solution designed to deliver
the best outcomes to help operators
achieve their specific operations and business needs.
As the Permian Basin application illustrates, the tight-radius ESP can be
combined with various other production
management technologies to enhance
overall benefits. In that case, the integrated
solution included a VSD with control
system software to reduce power and
downtime costs while increasing uptime
and ESP system reliability, intelligent
production software to clear gas lock situations and manage drawdown to help
the well produce longer, and round-theclock production monitoring software
and real-time decision support during the
first 90-120 days of production (when
the risk of reliability issues and shutdowns
related to erratic production, frac flowback
water, and other unstable downhole conditions is greatest).
Integrating artificial lift with production
chemicals can further optimize recovery
and returns. Three primary challenges to
production longevity-flow assurance, integrity management, and production optimization-can be addressed by combining
production chemicals with artificial lift
systems.
Chemical inhibition programs enhance
flow and extend the life of an artificial
lift system by inhibiting or even preventing
blockages from forming as a result of
scale, asphaltenes and paraffins. Operators
can enhance the integrity of ESPs and

completion systems while keeping their
personnel safe with chemical integrity
management programs that inhibit issues
associated with hydrogen sulfide. Over
the life of a field, declining well performance can be rejuvenated through
chemical remediation programs and posttreatment monitoring services. These programs help to not only increase production
and extend the life of the well, but also
to capture stranded reserves.
The greatest challenge to including
production chemicals in an integrated
production solution is that production engineers often lack the domain expertise
to make decisions about what chemical
treatments can best improve performance
from artificial lift systems. A solution
that leverages an expert, multidisciplinary
production team offers the best chance
for protecting the long-term viability of
the reservoir, the wellbore and the lifting
system.
❒
JEHIEL AGUILAR is North American region artificial lift services engineering manager for Baker Hughes.
Since joining Centrilift (now Baker
Hughes) in 1993, Aguilar has served
in various engineering operations and
management positions in Ecuador,
Guatemala, Mexico, Peru, and the
United States. Prior to joining Baker
Hughes, he worked for Peruvian companies Petrotech and Propetsa. He
holds an engineering degree from Engineering University in Peru.

CRISTIAN VON ZEDTWITZ is unconventional segment manager, artificial lift services, for Baker Hughes.
Since joining the company in 2001,
he has served in various completions
and production engineering field, sales
and management positions in Argentina, Colombia, Ecuador, Peru, and
the United States.

Coming In July

With production declines as high
as 80 percent in unconventional
plays, the New Technology special
reports spotlight emerging solutions
to rejuvenate production and boost
ultimate recoveries-from singlestage mechanical and chemical treatments to full-scale refracs. Guest
authors also present advances in
high-resolution stress and fracture
identification, and new tools for assessing frac effectiveness from flowback and produced water analysis.
JUNE 2015 79

American Oil and Gas Reporter - June 2015

Table of Contents for the Digital Edition of American Oil and Gas Reporter - June 2015