Case study: Norway

Automated fluids monitoring service
enables rapid barite sag detection
to avoid hours of NPT
A major operator in the North Sea
faced serious barite sagging
challenges while drilling with aninvert emulsion fluid (IEF) system.

The AFM service automatically detects
the slightest mud weight trends withgreater speed and precision than ispossible using manual methods.

The IEF system was lab tested
against many risks—barite sagging
included—prior to developing the final
fluid program. While the IEF system’srheology remained in-spec duringdynamic conditions, it could notwithstand prolonged static conditions
at high temperatures and pressures
downhole. These conditions eventuallycaused the barite to sag or drop outof the IEF system, leading to out-ofspec mud weight and rheology andpotential plugging of the string.

These measurements areautomatically analyzed andtransmitted to remote Baker Hughes
fluids experts tasked with actively
monitoring the fluid properties andother key drilling parameters. These
remote fluid engineers verify thedata by comparing it to manualrheology and mud weight data
recordings submitted by the rig crew.
Once verified, the data are used toengineer any necessary adjustments
to the fluid system. These findings
and recommendations are then
immediately relayed to the client.
Once these recommendations areapproved, the AFM service guides
the rigsite personnel to make thenecessary adjustments to avoid
barite sagging and maintain
optimal safety and performance.

The operator asked Baker Hughes
to develop an early warning solution
to identify the onset of barite sagging.
This would allow the drilling teamin the remote center to detect slightchanges to mud weight much fasterthan is possible for a rig crew relying
on less frequent manual checks.
Without early detection and quick
action, the level of barite sag would
make remediating the fluid properties
much more challenging—requiring
long circulation times and increasing
the risk of stuck drillstring.

Developing an automatedmonitoring solution

Baker Hughes proposed its i-Trak™
automated fluids monitoring service,utilizing the i-Trak™ automatedfluids monitoring unit (AFM) for
continuous monitoring of fluid anddrilling parameters combined with
automated analysis and real-time,
expert technical support.

Challenges• Barite sagging risks due to:- prolonged tripping operations- extended static conditions- reduced circulating rates• High risk of NPT due to bariteinduced string plugging

Results• Reduced time to identify barite
sag or changes in mud weight• Minimized NPT by avoiding
string plugging and long
circulation times• Aided remote operations
to maintain specified mudweight and avoid additional
barite sagging

Maintaining fluids
specifications

The real-time monitoring andautomated analysis provided by i-Trak
AFM service identified variations in mud
weight sooner, giving the onshore teaman early indication of barite sagging.
Prior to implementing the AFM service,
rig personnel evaluated fluid rheology
and density data every six hours. Thissignificant time delay under these
conditions would have allowed barite
sag issues to progress to the pointof that lengthy fluid recovery actions
to avoid potential plugging of thedrillstring. The AFM service comparedbakerhughes.com

the live mud weight and rheological
data with manual checks at 15-minuteintervals, a significant time savings
that prevented barite sag issues frombecoming a larger problem.
The service provides this real-timedata to all key wellsite personnel on
the drilling job, the onshore fluids team,and other support personnel inthe office.

The fluids team applied the mud
remedies required to maintain mud
weight and rheology per specs.
By reducing the time to identify theonset of sagging, the service also
guided the fluids team on the rightcourse of action to treat the fluid early
and avoid long hours of circulation
time typically required to remediatea barite sagging problem.

The i-Trak automated fluids monitoring service identified barite sag within 30 minutes of its firstoccurrence. This allowed the drilling team to take corrective actions and eliminate the issue
faster than the sag problem could even be identified using conventional methods.

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