American Oil and Gas Reporter - May 2015 - 105

The right compression equipment and operational strategy can optimize production
from multiwell pads in horizontal resource plays with characteristically high decline
rates. For example, a single compressor can accommodate gas production from all the
wells on a pad and distribute a percentage of the produced gas to gas lift valves to assist
with oil production while maintaining the flexibility to accommodate changes in production over time.

ment leasing options. "A properly designed
package will have adequate flexibility to
accommodate changes in production over
time, allowing the same equipment to be
kept in service for the maximum amount
of time," Knox comments.
"With the right package, the operator
can install the system understanding that
there will be a decline in the inlet compressor flow rate, or perhaps increased
discharge pressure when a pipeline on the
outlet side becomes full, without having
to worry about switching compressors
within a short period," he goes on.
Responding To Changes
But even with inherent flexibility in
compressor package designs, resource
play decline curves mean pad production
profiles are changing continually. Across
its rental fleet, Knox says individual units
tend to remain on location for about three
years before production requirements mandate installing a different horsepower.
"Responding to changing conditions
gets directly to the core benefit of compressor leasing: The producing company
does not have capital tied up in owning
compression equipment that may not fit
its needs when the production situation
changes," he states. "From the producer's
standpoint, an adequately sized rental
fleet can provide all the assets necessary
to serve current and future needs as compression requirements change."
That makes it crucial for fleet operators
to have a full range of compressor sizes
ready to go, and was the catalyst behind
Compressco Partners' acquisition of Compressor Systems Inc. last year, Knox suggests. "The goal is to give the producer
access to everything from a 20-horsepower

vapor recovery or gas lift package to a
2,500-horsepower unit for a gathering or
central delivery point, and to be able to
install an individual unit or multiple units
as needs dictate," he holds.
Whatever the size or type of compressor, the bottom-line measure of performance is run time. "If compression
goes down, it can cause production issues
that can be difficult to resolve and take
time to recover from," Knox notes.
"Whether handling associated gas production, operating gas lift valves, or both,
wells cannot generate optimal revenue if
the compressor is not running."
For that reason, he says, the demand
for automation and real-time remote monitoring capabilities continues to grow.
"Monitoring conditions such as temperatures, pressures and fluid levels allow
logic to be built into a telemetry system
to get ahead of problems before a shutdown
or alarm can occur," Knox explains. "By
identifying early warning signs, highly
qualified technicians can diagnose a potential issue and dispatch mechanics with
the right parts prior to a mechanical problem. It gives the operator improved run
times and allows him to achieve his ultimate goal of producing more gas."
Emissions compliance is another dominant factor shaping trends in compressor
technology. Knox credits engine manufacturers with taking proactive steps to
keep pace with ever-tightening regulatory
mandates.
"Manufacturers have further reduced
the exhaust emissions of lean-burn engines
so that they comply with all applicable
standards. Manufacturers also are designing engines with catalytic reductions
in mind," he remarks. "At this point, I
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American Oil and Gas Reporter - May 2015

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