American Oil and Gas Reporter - January 2017 - 90

Production Technology
gives us the ability to produce the liquid
and naturally separate the gas," he says.
Production engineers working on wells
with high gas-to-liquid ratios typically
want the largest casing size available for
maximum flexibility in selecting downhole
gas separation equipment, Holland observes. They also want pumping units
with good gas-handling capabilities that
provide a range of depths at which they
can be set to provide the best intake pressure and maximum production, while
providing for flexibility to accommodate
well changes.
"Historically, ESPs have been a 'period-in-time' solution in a well's life cycle.
We are doing everything we can to ensure
ESP can be applied throughout the entire
well life cycle by extending the production
range and being able to set ESPs deeper
while also handling the gas," he says.
The CENtrilift PASS system helps operators by reducing the number of equipment change-outs as well production
varies, Holland says. Instead of switching
ESPs as output declines, the Baker Hughes
unit's flow range provides hands-off operations as production drops, and its
smaller size allows more placement options
as operators pursue optimal setting depths
for maximum hydrocarbon inflows.
Like the 400 series units, Holland says
the 300 ESP system provides natural separation of gas slugs and production liquids
through the CENesis PHASETM multiphase

encapsulated production system, which
encases the entire ESP system. The design
also protects the motor lead extension
during installation in deviated or horizontal
wellbores, and reduces motor overheating
by diverting fluid past the ESP motor,
Holland says.
"Encapsulate the ESP system inside a
shrouded unit, and you have a really interesting flow path for the liquid and gas
to take," he says. "The PHASE system is
a very unique gas separation tool. The
PHASE system's limitation was the well
casing size. By creating the PASS system
technology, a new PHASE system was
developed for slim casing design. Now,
there are two great technologies that,
when combined, literally can handle any
gas-to-liquid ratio or any slugging combination that an asset can give."
Rigless Interventions
The industry is only in the beginning
stages of seeing what small-diameter ESP
equipment can do, Holland goes on. Baker
Hughes has unveiled its TransCoilTM rigless-deployed ESP system, which he describes as a unit that delivers the production
and reserve recovery enhancements of a
traditional ESP while eliminating the
need for a rig during installation.
"That means you don't have to kill
the well, saving time and money while
drastically reducing risk. And using a
coiled tubing-deployed ESP lets the op-

The CENtrilift PASS™ ESP system from Baker Hughes includes
a new high-performance FLEXPumpER™ series electric submersible pump with a flow range
from 50 to 3,000 barrels a day.
It provides operators with the
flexibility required in dynamic
well conditions to minimize ESP
system change-outs and nonproductive time while reducing
operating expenses. The pump
is designed for maximum production and ultimate reserve recovery from conventional and
low-flow mature oil fields, and
unconventional resource plays
with changing production rates.

90 THE AMERICAN OIL & GAS REPORTER

erator leave the production tubing in the
well during installation," Holland says.
"But eliminating the rig is half the battle.
By connecting an inverted ESP system
directly to powered CT, the TransCoil
system eliminates the conventional ESP
power cable-to-motor connection and an
in-well wet electric connection, removing
the weakest link in ESP systems."
The TransCoil system uses a CT setup
at a well location to deploy its ESP unit
through tubing or in a cased well environment, he says. It can be set in a range of
completion systems, but Holland points
out, "If an event comes around where that
well needs to be worked over, whether the
operator wants to change out the equipment
and move it somewhere else or whatever
the situation may be, no rig will be needed.
The CT setup gets over the well, pulls the
string out, and deploys another unit, getting
wells on production faster."
The system, which is effective to
12,000 feet, is being used in pilot projects
in the Middle East and the Asia/Pacific
region, he says.
"We are looking at wells that are really
deep, and some with very high temperatures. This technology changes the spaces
that we can play in," Holland concludes.
Nanofluidity
Nanofluidity is the quality or state of
being fluid at the atomic, molecular and
supramolecular scales. Revelant Nanofluidity Technology stabilizes nanofluidity
downhole using nanophysics to drive
better oil chemistry during production
and transport.
Monte Swan, Revelant's chief scientist,
says the company's EnercatTM tool manipulates fluid chemistry, stabilizing viscosity and minimizing or preventing paraffin crystallization, asphaltene flocculation
and scale precipitation. Using the tool
can "reduce and even replace traditional
mechanical, chemical and thermal mitigation methods," Swan says. "This tried
and proven innovation stabilizes and increases production, and reduces operating
expenses while minimizing environmental
and regulation costs."
Brian Herman is the inventor and developer of Enercat for the oil and gas industry. Swan says Herman first installed
the tool in a Northwest Canadian well experiencing paraffin pour-point problems.
The tool's implementation produced significant paraffin, asphaltene, and heavy



American Oil and Gas Reporter - January 2017

Table of Contents for the Digital Edition of American Oil and Gas Reporter - January 2017

Contents
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