advanced technologies resolved esp monitoring problems.pdf
TRANSCRIPT
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Benefits
Decreased risk of electrical
interference between ESP and
downhole gauge
Reduced rig time with better
completion design
Increased reliability of motortemperature sensor
Eliminated need for additional
downhole cabling and equipment
to monitor ESP system
Measured additional and
redundant parameters
Well background and challenges
Obsolete equipment
Electrical interference between the
ESP and the downhole gauge ESP trips because of bad data
Baker Hughes solution and results
SureSENS 125 permanent downhole
monitoring system
SureFlo 298 flowmeter system
WellLIFT E ESP monitoring system
Reduced risks of ESP downtime
Old equipmentA major North Sea operator has used Baker Hughes
electrical submersible pumping (ESP) systems and
permanent downhole gauges for more than
10 years. The systems were configured across a
venturi flowmeter and used on a project with more
than 20 wells.
The downhole gauge instrumentation collected
critical pressure and temperature data and used
the data to calculate accurate and reliable flow
rates. The downhole gauges also protected the
ESP systems from failures. They warned the the
operators when an ESP was either overheating or
operating outside of its design parameters.
As anticipated, the equipment had a finite life
cycle and began to produce electrical interference
between the ESP and the downhole gauge. The
instrumentation was also producing bad data that
caused the ESPs to be tripped.
New technologyIn 2008, Baker Hughes identified the biggest
problem was the age of the system and equipment.
Upgrading the technology would address the
equipment obsolescence and eliminate the other
problems that were occurring.
After discussions about new Baker Hughes
technologies, the operator selected a downhole
instrumentation technology that would also bepart of the design of the upper completion.
Tubing
SureSENS 125 Gauge andSureFlo 298 Flow Meter
Packer withFeed-through
ESP Pump
WellLIFT DischargeGauge Unit
Mono-conductor TECinternally connected to ESP cable
ESP Ported Headand Seal Assembly
ESP Motor
WellLIFT MotorGauge Unit
Cable Splice
ESP Cable
Mono-conductor TEC
TEC Cable (TubingEncapsulated Cable)
C a s e H i s t o r y
Advanced Technologies ResolvedESP Monitoring ProblemsBaker Hughes reduced rig time with effective completions design
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The operator decided that the existing ESP technology would remain
the same, but the downhole gauge architecture would change. The
operator selected the following Baker Hughes technologies:
SureSENS125 downhole gauges to provide accurate pressure
and temperature data for the life of the project
SureFlo298 flowmeter system to give real-time production
data without affecting recovery potential
WellLIFT EESP monitoring system to supply downhole, surface
and diagnostic parameters, enhance system management, and
prolong the equipment life
Both the operator and Baker Hughes wanted to make sure the
proposed new technology would meet the future requirements
for the surface equipment. To avoid the problems associated with
integration into the nearly full, existing system, a new, separate
system was implemented.
The new system used the same Baker Hughes software and
allowed the data from the SureSENS 125 gauge and WellLIFT ESP
monitoring system to be collected in a single place before being
handed off to the clients control and database systems.
Using the new technologies, the customer has worked over a
number of wells and confirmed a significant increase in overall
system reliability.
Real-time productiondata with the SureFlo 298
flowmeter system.
WellLIFT ESP monitoring system.
2011 Baker Hughes Incorporated. All rights reserved. 30690
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