Job description for a subsea engineer in offshore operations?

Subsea Engineer — Offshore Operations (Job Description)

Ensures safe, reliable operation of subsea well control and production systems offshore. Owns integrity of BOP stacks, subsea control systems, trees/manifolds, risers, and umbilicals; plans and executes installation, testing, intervention, and maintenance to minimize NPT and safeguard barriers.

I. Core Responsibilities (Day-to-Day)

I.1 Plan, execute, and document subsea operations: BOP/LMRP runs, connectors, wellhead engagement, tree/manifold installation, IWOCS hookup, and workover operations.
I.2 Maintain well control equipment integrity: function tests, pressure tests, AMF/EDS verification, sealing integrity checks, annular/elastomer inspection, and closing-time validation.
I.3 Operate and troubleshoot subsea control systems (MUX/EH/HC): diagnose pod failures, solenoid/valve issues, communication faults, hydraulic leaks, and sensor anomalies.
I.4 Lead ROV interfaces: tooling selection, hot-stab operations, intervention panel use, flying lead installation, visual/DPTH inspections, and debris removal planning.
I.5 Manage riser and tensioning systems: landing string deployment, telescopic joint/heave compensation checks, tensioner setpoints, slips/joint inspection, weak point verification.
I.6 Execute pressure testing programs: FAT/SIT/SAT, pre/post-operation tests of BOP rams/annulars, wellhead connectors, H4/collet connectors, tree valves, jumpers, and hubs; record test charts and acceptance criteria.
I.7 Barrier and SIMOPS management: confirm primary/secondary barriers, lock/open status, isolation plans; coordinate with drilling, marine, and production during overlapping operations.
I.8 Equipment readiness and spares: maintain CMMS records, critical spares inventory (seals, pods, accumulators), repair/overhaul schedules, and preservation for standby equipment.
I.9 Emergency response and well control support: EDS logic validation, autoshear/deadman readiness, hot-line kill/bleed-up strategies, loss-of-hydraulic/communications procedures.
I.10 Assurance and compliance: implement PTW/LO/TO, Management of Change, risk assessments (JSA/TRA), lifting plans, and OEM compliance for upgrades/obsolescence management.
I.11 Data and reporting: daily subsea status, NPT coding, test packs, torque/tension logs, as-built redlines, lessons learned, and handover notes.
I.12 Vendor and class/survey coordination: witness tests, surveyor engagement, third-party audits, and recertification logistics.

I.A Operational Calculations (Examples)

I.A.1 Hydrostatic head for test/kill lines: \( P = \rho g h \)
I.A.2 Gas accumulator sizing (isothermal estimate): \( P_1 V_1 = P_2 V_2 \); verify closing volumes for worst-case sequence.
I.A.3 Connector preload vs. gasket load margin: \( F = P A \), ensure preload = design pressure load with safety factor.
I.A.4 Riser tension envelope check (simplified): total tension \( T = T_\text{top} - W_\text{submerged} \); maintain above minimum collapse/instability criteria.

II. Required Skills and Physical Demands

II.A Technical Skills

II.A.1 Subsea well control systems: BOP stacks (ram/annular), LMRP, AMF/EDS logic, autoshear/deadman testing.
II.A.2 Control systems: MUX/electro-hydraulic/PLC, pods, solenoids, SPM valves, shuttle valves, subsea sensors.
II.A.3 Trees/manifolds/jumpers: hub/connector types, gasket energization, torque/turns control, leak paths, sealing verification.
II.A.4 Riser and landing strings: tensioner/heave compensation, telescopic joint, flex joint limits, VIV mitigation, slip joint management.
II.A.5 Umbilicals and flying leads: hydraulic/electrical/fiber elements, HFL/EFL handling, MCS/IWOCS deployment, flushing and cleanliness.
II.A.6 ROV operations: intervention tooling, hot-stabs, torque tools (Class 1–7), visual inspection criteria, subsea metrology.
II.A.7 Pressure testing and hydraulics: test charts, acceptance criteria, relief settings, fluid cleanliness (ISO 4406), gas precharge.
II.A.8 Integrity management: NDE basics, elastomer compatibility, corrosion/erosion awareness, obsolescence/risk ranking.
II.A.9 Standards familiarization: well control and subsea equipment standards, class/society rules, and OEM service bulletins.
II.A.10 Documentation: test packs, as-builts, redlines, MoCs, spares BOM, and CMMS work orders.

II.B Soft Skills

II.B.1 Risk-based decision-making under time pressure; clear barrier management communication.
II.B.2 Leadership in a multi-discipline environment; ability to brief crews and vendors succinctly.
II.B.3 Root cause analysis and incident learning capture; precise technical writing.
II.B.4 Stakeholder alignment across drilling, marine, production, ROV, and logistics.

II.C Certifications & Physical Demands

II.C.1 Offshore survival, HUET, and valid offshore medical; confined-space awareness.
II.C.2 Accredited well control (subsea) certificate appropriate to role and jurisdiction.
II.C.3 Ability to work 12-hour shifts for multi-week hitches; climb ladders, handle deck motions, manage tool lifts within policy limits.
II.C.4 Color vision adequate for panel indications; hearing protection compliance in high-noise areas.

III. Tools, Software, and Equipment

III.1 Subsea hardware: BOP stacks/LMRP, rams/annulars, connectors (H4/collet), wellheads, trees, manifolds, jumpers, hubs, seals/gaskets.
III.2 Control equipment: MUX/EH pods, accumulators, HPUs, hydraulic test pumps, pressure/temperature sensors, gauge and chart recorders.
III.3 Riser systems: marine riser, landing string, tensioners, flex joints, telescopic joint, heave compensators, weak links.
III.4 ROV systems and tooling: torque tools, hot-stabs, intervention panels, cutter/saw tools, cleaning brushes, metrology frames.
III.5 Test/measurement: deadweight testers, calibrated pressure transducers, flowmeters, cleanliness monitors (particle counters), NDT gauges.
III.6 Software: CMMS (maintenance and spares), PLC/HMI diagnostic suites, subsea control diagnostics, dynamic riser analysis software, CAD, digital twin/condition monitoring dashboards.
III.7 Survey/positioning: USBL/LBL beacons, acoustic transceivers, depth/altitude sensors, attitude/heading reference systems.

Toolchain Snapshot

III.T1 CMMS for work orders/spares; digital forms for test packs; PLC/HMI tools for pod diagnostics.
III.T2 Riser analysis suite for tension/VIV envelopes; CAD for as-builts; condition monitoring for accumulators and valves.
III.T3 ROV control/telemetry and survey positioning systems for installation accuracy and verification.

IV. Work Environment

IV.1 Offshore-based on MODUs, intervention vessels, or production facilities; occasional onshore yard/SIT/FAT attendance.
IV.2 Rotations typically 14/14 or 28/28; 12-hour shifts with on-call response for critical operations.
IV.3 Exposure to heavy weather, deck operations, crane lifts, and pressurized systems; strict adherence to PTW and lifting plans.
IV.4 Travel varies with campaign cadence; rapid mobilization for stack pulls, interventions, or integrity incidents.

V. Reporting Lines and Cross-Functional Interfaces

V.1 Reports to: Offshore Subsea Superintendent or Offshore Installation Manager; functional line to Wells/Subsea Operations Manager (estimated based on typical offshore orgs).
V.2 Direct interfaces: Drilling Supervisor/Company Rep, Toolpusher, Driller, Marine/DP team, ROV Supervisor, Production/Operations Lead, HSE Lead, Logistics Coordinator, OEM Field Service Representatives.
V.3 Handoffs: test certificates, NPT logs, barrier status, as-built drawings, CMMS updates, spares requests, MoC packages, and punch lists.
V.4 Governance interfaces: survey/class representatives during recertification, regulatory inspectors during audits (as required by jurisdiction).

Deliverables & Interfaces

V.D1 Deliverables: approved procedures, risk assessments, pressure test packs, function test records, EDS/AMF validation, daily subsea reports, lessons learned, and close-out dossiers.
V.D2 Interfaces: drilling/completions and production teams for SIMOPS, marine for weather/tow/DP limits, ROV/survey for installation and verification, and shore base for logistics/spares.

VI. Career Ladder and Progression

VI.1 Next roles: Senior Subsea Engineer, Subsea Superintendent, Subsea Operations Lead, Well Control Equipment Manager, Offshore Installation Manager (with broader operations exposure).
VI.2 Advancement prerequisites: successful leadership of stack pulls and major interventions, zero HSE incidents, strong test/assurance records, competence sign-offs, and enhanced well control/subsea systems accreditation.
VI.3 Broadened scope: project engineering for subsea tie-backs, standardization/obsolescence programs, digital condition monitoring deployment, and vendor/framework management.

Progression Trigger

VI.P1 Typically promoted after 6–10 complex offshore campaigns or 12–18 months of incident-free operations, plus completion of advanced subsea systems and well control certifications (estimated; varies by operator/contractor).
VI.P2 Demonstrated ability to plan/execute EDS drills, manage full BOP overhaul/recertification, and deliver documented performance improvements (e.g., reduced function test time by =20%).