DRILLING & COMPLETION TECH DIGEST • DEPARTMENTS
RSS sets record, saves 7 days
of drilling time offshore UK
160 Amplitude,e,e, rprprpmm
Amplitud 140
120 100
80 60
40 20
0 Non-dampene
Non-dam penedd
pene Competitor
HFTO HF
TO supp
supprereressor ssor
Using the suppressor tool decreased shock peaks by 64% relative to non-damp-
ened BHAs, according to simulations SLB performed using its IDEAS platform.
Simulations demonstrate how HFTO suppressor tool
can reduce shock amplitude in Permian wells
Recent simulations have shown that
using shock and vibration suppressor
technology can reduce shock amplitude
by 64% in Permian Basin wells, com-
pared with offset wells, according to SLB.
Operators in this region often experi-
ence excessive shock and vibration, par-
ticularly high-frequency torsional oscil-
lation (HFTO). Excessive HFTO is the
leading cause of downhole tool failures,
including cracked drill collars, broken
measurement tools and electronic com-
ponent failures. These can lead to addi-
tional trips, time and cost.
In the past, Permian operators have
used different types of shock and vibra-
tion dampening tools to mitigate the
effects of HFTO, but success has typically
been limited. Field data showed simi-
lar spikes in amplitude and frequencies
between dampened and non-dampened
BHAs. These high and sporadic shock
amplitudes resulted in costly, fatigue-
induced drillstring failures, including
twist-offs and broken components in the
rotary steerable and MWD equipment.
SLB designed its HFTO Suppressor tool
to reduce downhole shock and vibra-
tion while drilling in challenging for-
mations. The company used IDEAS, its
integrated dynamic design and analysis
platform, to simulate HFTO at various
points throughout the BHA. This helped
SLB engineers to determine the ideal
location for the HFTO Suppressor within
the assembly.
The IDEAS simulations verified that
the mechanical suppressor tool could
reduce shock amplitude by 64% com-
pared with drillstrings without dampen-
ing tools. Additionally, the data revealed
a 48% reduction in shock amplitude com-
pared with other shock and vibration
dampener tools.
In a North Sea production well, an oper-
ator sought to drill from a whipstock set in
13 ⅜ -in. casing in soft Tertiary formations
and complete the section drilling through
hard chalk formations. Other challenges
included kicking off successfully from
the main bore, as well as overcoming
challenging directional profile with anti-
collision. To achieve this, Weatherford deployed
an integrated solution that included the
950 Magnus rotary steerable system (RSS).
The strategy was to use the RSS on a sec-
ond bit run through the chalks. Based on
previous offset wells, the main challenges
expected for this section were fluid losses,
wellbore stability, abrasive wearing and
vibration. The well profile was S-shaped with a
3-3.5° dogleg severity requirement, with
the maximum inclination building to 40°
and turning a total 246° azimuth from
kickoff to section TD.
The Magnus RSS drilled a total footage
of 6,080 ft across the section, maintaining
a rate of penetration average of 50 ft/hr.
The optimized efficiency saved the opera-
tor seven days of drilling time.
The run met all directional objectives
and even achieved a record for the longest-
drilled run in the 12 ¼ -in. section to date
in the field.
LWD ultrasonic imager identifies fractures in Turkey well
In Turkey, an operator was encounter-
ing challenges logging the well due to
borehole conditions. The operator was
seeking high-resolution borehole image
data to identify fractures in the vertical
well, which was filled with 14.84 lb/gal
oil-based mud.
For this project, Weatherford ran its
UltraWave logging-while-drilling (LWD)
ultrasonic imager. The logging suite also
included a real-time telemetry system,
gamma ray, multi-frequency resistivity
and sonic tools. UltraWave allowed the
operator to directly identify fractures
and other features in the borehole even
in the presence of heavy mud and a high
concentration of solids. The LWD tools
were able to acquire gamma ray, resis-
tivity and sonic data together with high-
amplitude images from the UltraWave
for reservoir evaluation and completion
planning. Weatherford’s Magnus RSS helped to
save an estimated seven days of drill-
ing time in a North Sea production well
by overcoming challenges around fl uid
losses and wellbore stability.
D R I L L I N G C O N T R AC T O R • M A R C H/A P R I L 2023
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