Page 39: of Offshore Engineer Magazine (Jan/Feb 2026)

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FROM REACTIVE TO

PROACTIVE:

Managing Downhole

Vibration in Complex Wells © Neo Oiltools of well architecture. Extended-reach wells, high-pressure/ and RPM. But with operators facing strict cost and sched- high-temperature developments and aggressive directional uling constraints, reactive adjustments offer limited pro- trajectories are placing bottomhole assemblies (BHAs) un- tection against nonproductive time.

der greater mechanical and thermal stress. “Identifying the cause of the vibration in real time al- “These conditions have repercussions, creating a com- lows drillers to proactively adjust operations so drilling plex interplay of tri-axial vibrations created at the interface can progress and wear on equipment can be reduced,” between the rock and bit, that coalesce into nodes of dam- said Feasey.

aging dysfunction that lead to excessive tool wear, erratic Today, Feasey explains, tools placed within the BHA are rates of penetration (ROP), and unplanned trips, which being used to suppress, dampen, isolate or alter vibration undermine effciency and infate well costs,” he added. energy before it escalates. This allows drillers to apply more

As laterals extend and geometries tighten, torque, drag aggressive designs and drilling practices without increasing and friction intensify. In mature offshore basins, where vibration magnitude to a level that compromises reliability.

reservoirs are compartmentalized and wellbores closely The economic stakes, as Feasey claims, are considerable.

spaced, drilling often requires sharper build-and-turn sec- “Deepwater drill ships are commanding day rates around tions and narrower operating windows. USD $500,000. For a well with a base drilling schedule of “Working within these geometries in exacting downhole 80 rig-days, that equates to roughly USD $40 million in environments increases the range of vibration-triggering rig cost alone,” he said.

events that impact the drilling schedule,” Feasey pointed out. If vibration-related issues extend a program by just fve days, incremental rig cost could reach USD $2.5 million.

When services, consumables, additional runs and logis-

FROM SURFACE ADJUSTMENTS TO tics are factored in, total additional well cost can easily

DOWNHOLE CONTROL

Historically, vibration mitigation relied on adjusting double. Across multi-well campaigns, the fnancial im- surface drilling parameters such as weight-on-bit (WOB) pact becomes material.

JANUARY/FEBRUARY 2026 OFFSHORE ENGINEER 39