Benefi ts

Decreased risk of electrical interference between ESP and downhole gauge

Reduced rig time with better completion design

Increased reliability of motor temperature sensor

Eliminated need for additional downhole cabling and equipmentto 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 equipment

A 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 confi gured across a venturi fl owmeter 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 fl ow 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 fi nite 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 technology

In 2008, Baker Hughes identifi ed 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 be part of the design of the upper completion.

Tubing

SureSENS 125 Gauge and SureFlo 298 Flow Meter

Packer with Feed-through

ESP Pump

WellLIFT Discharge Gauge Unit

Mono-conductor TECinternally connected to ESP cable

ESP Ported Headand Seal Assembly

ESP Motor

WellLIFT Motor Gauge Unit

Cable Splice

ESP Cable

Mono-conductor TEC

TEC Cable (Tubing Encapsulated Cable)

C a s e H i s t o r y

Advanced Technologies Resolved ESP Monitoring Problems Baker Hughes reduced rig time with effective completions design

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:

SureSENS™ 125 downhole gauges to provide accurate pressure and temperature data for the life of the project

SureFlo™ 298 flowmeter system to give real-time production data without affecting recovery potential

WellLIFT E™ ESP 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 client’s control and database systems.

Using the new technologies, the customer has worked over a number of wells and confi rmed a signifi cant 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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