Responsibilities of a directional drilling assistant offshore?

Directional Drilling Assistant (Offshore) — Role Profile

Supports the offshore directional driller and MWD/LWD personnel in executing wellbore placement, BHA readiness, real-time monitoring, and compliance with HSE and drilling program requirements.

I. Core Responsibilities

I.1 — Execute pre-job checks: verify BHA components, non-mag spacing, make-up torque, toolface offsets, sensor placement, batteries, and memory clearance.
I.2 — Assist with rig-up/rig-down of MWD/LWD surface gear, decoder, sensors, and cabling; conduct leak and pressure tests per procedures.
I.3 — Manage tool readiness: assemble/disassemble MWD/LWD sub, pulse/EM hardware, stabilizers, subs; maintain a clean, organized wellsite workshop.
I.4 — Support downhole comms: monitor mud-pulse/EM telemetry quality, adjust settings under instruction, troubleshoot signal/noise issues with the driller and mud team.
I.5 — Real-time surveillance: track inclination/azimuth, gamma, shock/vibration, stick–slip, downhole pressures; flag deviations and trends to the directional driller.
I.6 — Survey QA/QC: validate surveys against program tolerances, apply magnetic corrections as directed, maintain survey and anti-collision files.
I.7 — Slide/rotate support: prepare slide sheets, calculate slide lengths/percent, record toolface and connection times, capture parameters and outcomes.
I.8 — Parameter management: track WOB, RPM, flow, SPP, torque and drag; notify when approaching operating limits or programmed boundaries.
I.9 — Hydraulics checks: confirm flow, density, and pressure align with program; assist in identifying pack-off, losses, or motor stall indicators.
I.10 — Data handling: download memory data, back up logs, maintain DDR entries, daily reports, end-of-well documentation and handover notes.
I.11 — Inventory and spares: manage consumables (batteries, o-rings, elastomers), critical spares, shipment prep and receiving; record serial numbers and hours.
I.12 — BHA changeovers: assist with trips, motor/RSS swaps, reamer and stabilizer changes; verify part numbers and configuration match the drilling plan.
I.13 — Interface with rig crew: coordinate pipe tallies, depth tracking, connection procedures, and floor communications during slides and orienting.
I.14 — HSE compliance: participate in PTW, risk assessments, toolbox talks, JSAs; ensure barricades, lifting practices, and lock-out/tag-out are followed.
I.15 — NPT mitigation: support troubleshooting for telemetry loss, sensor failure, motor stalls, plugging; execute documented contingency actions.
I.16 — Housekeeping and custody: keep the DD cabin and workshop orderly; maintain custody of tools and calibration/pressure test records.

I.A Relevant Calculations (field-use)

I.A.1 — Dogleg Severity (deg/30 m or deg/100 ft):
\( \mathrm{DLS} = \dfrac{\cos^{-1}\!\left(\cos I_1 \cos I_2 + \sin I_1 \sin I_2 \cos \Delta \mathrm{Az}\right)}{\Delta \mathrm{MD}} \times K \)

K = 30 m or 100 ft scale factor to express DLS per interval.
I.A.2 — Slide percent and length (estimated):
\( \text{Slide \%} \approx \dfrac{\text{Target Build Rate}}{\text{Motor Yield (Build Rate)}} \times 100 \)

\( L_{\text{slide}} \approx \text{Slide \%} \times \Delta \mathrm{MD} \)
I.A.3 — Toolface effectiveness (to gauge curvature efficiency):
\( \eta_{\text{TF}} = \cos(\Delta \mathrm{TF}) \), where \( \Delta \mathrm{TF} \) is the difference between planned and actual toolface.

II. Required Skills and Physical Demands

II.A Technical Skills

II.A.1 — Fundamentals of wellbore placement, survey methods, anti-collision principles, and BHA components (motors, RSS, non-mag collars, stabilizers).
II.A.2 — Telemetry systems (mud pulse/EM), surface decoding, noise mitigation, and signal QA/QC.
II.A.3 — Basic hydraulics and hole-cleaning indicators; recognition of stall/pack-off/losses signatures from surface trends.
II.A.4 — Torque-and-drag and parameter trending; understanding operating envelopes and limits.
II.A.5 — Competence in survey file handling, depth/tally control, and data integrity practices.
II.A.6 — Familiarity with RSS/motor slide execution workflow and toolface control steps.

II.B Soft Skills

II.B.1 — Clear radio/face-to-face communication on the rig floor and in the DD unit.
II.B.2 — Situational awareness, adherence to procedures, and attention to detail under time pressure.
II.B.3 — Teamwork with rig crew, fluids, geology, and wellsite leadership; positive handover discipline.
II.B.4 — Accurate record-keeping and reporting.

II.C Physical Demands

II.C.1 — Offshore 12-hour shifts (day/night) with extended standing, stair climbs, and exposure to vibration/noise.
II.C.2 — Manual handling of components up to ~25–35 kg (55–75 lb) using safe lifting and aids.
II.C.3 — Work in confined/limited-access areas; full PPE, including fall protection and H2S gear as required.
II.C.4 — Fit for offshore survival training and emergency drills.

III. Tools, Software, and Equipment

III.1 — MWD/LWD bottomhole tools: mud-pulse/EM transmitters, directional/gamma sensors, non-mag drill collars, stabilizers, subs.
III.2 — Directional systems: downhole motors, rotary steerable systems (support role), reamers, near-bit inclination/gamma (as applicable).
III.3 — Surface acquisition/decoding: MWD surface systems, rig floor displays, depth tracking, real-time monitoring platforms.
III.4 — Planning/analysis software: torque-and-drag calculators, hydraulics models, survey/anti-collision tools, spreadsheets.
III.5 — Test and hand tools: pressure test pumps, multimeters, pressure gauges, calipers, torque wrenches, lifting aids.
III.6 — Communications: intrinsically safe radios, intercoms; rig ESD/PTW interfaces.
III.7 — QA/QC and reporting: daily drilling report inputs, survey databases, end-of-well report templates.

Toolchain Snapshot

III.T1 — Real-time monitoring platform + MWD decoder + depth tracker.
III.T2 — Hydraulics/T&D quick calculators; survey/anti-collision checker.
III.T3 — Pressure test kit, multimeter, calibrated torque tools.
III.T4 — Non-mag handling stands, lifting slings, certified containers.

IV. Work Environment

IV.1 — Offshore rigs (jack-up, semi-submersible, drillship).
IV.2 — Rotations commonly 14/14 or 28/28; 12-hour shifts; day/night swing as required.
IV.3 — Mobilization via helicopter/crew boat; pre-mob medicals and survival/H2S training mandatory.
IV.4 — Exposure to marine weather, motion, and restricted space; strict PTW and HSE systems.

V. Reporting Lines and Interfaces

V.A Reporting Lines

V.A.1 — Directly reports to the Lead Directional Driller (offshore).
V.A.2 — Functional alignment with the MWD/LWD Engineer for tool operations and data quality.
V.A.3 — Takes operational direction consistent with the Operator’s Drilling Supervisor and the drilling program.

V.B Cross-Functional Interfaces

V.B.1 — Driller and Assistant Driller (floor operations, orienting, connection timing).
V.B.2 — Toolpusher and Night Company Representative (operational coordination).
V.B.3 — Mud/fluids specialist (telemetry quality, hydraulics, hole cleaning).
V.B.4 — Wellsite geologist/geosteering (survey/gamma correlation, target updates).
V.B.5 — Cementing, wireline, casing crews (as needed during stage transitions).
V.B.6 — Maintenance/electrical technicians (power, signal integrity, equipment repairs).

Deliverables & Interfaces

V.D.1 — Deliver to Lead Directional Driller: survey packets, slide sheets, parameter logs, deviation alerts.
V.D.2 — Provide to Operator’s wellsite team: daily updates on surveys, BHA status, tool health, NPT notes.
V.D.3 — Hand off at crew change: comprehensive shift handover and data backups.

VI. Career Ladder and Progression

VI.1 — Next roles: MWD Field Specialist or Junior Directional Driller (offshore).
VI.2 — Midstream roles: Directional Driller ? Senior/Lead Directional Driller ? Wellbore Placement/Geosteering Specialist.
VI.3 — Progression enablers: consistent survey/data QA, safe tool handling, competent slide execution support, strong reporting discipline.

Progression Trigger

VI.P.1 — Typically promoted after ~12–18 hitches or 8–12 wells with positive evaluations and zero high-potential HSE events.
VI.P.2 — Completion of offshore survival/H2S, industry well control (surface stack), and OEM tool familiarization courses.
VI.P.3 — Demonstrated ability to manage surveys end-to-end and lead slide/rotate documentation without supervision.

For job openings, search jobs on Rigzone.