Responsibilities of a technical manager in offshore oil projects?

I. Technical Manager (Offshore Oil Projects) — Core Responsibilities

Accountable for multi-discipline technical leadership from concept/FEED through EPCI, commissioning, and handover, ensuring safety, integrity, operability, and cost/schedule adherence in offshore developments.

I.1 Lead the integrated engineering program (subsea, pipelines, structures, topsides, electrical/instrumentation, controls, flow assurance) across FEED/EPCI, enforcing Basis of Design and performance standards.
I.2 Own technical assurance: plan and chair design reviews, HAZID/HAZOP/LOPA/SIL, constructability/operability reviews, independent verification, classification, and regulatory compliance (API, ISO 19901 series, DNV, NORSOK as applicable).
I.3 Manage interface engineering across packages (SURF, drilling/completions, FPSO/Topside, export pipelines, power, telecom), maintaining Interface Registers and Interface Control Documents.
I.4 Control Management of Change (MOC): triage Technical Queries (TQs), concessions, deviations, non-conformances (NCRs), ensuring impact analysis on safety, integrity, RAM, cost, and schedule.
I.5 Oversee contractor and vendor engineering: scope, technical bid evaluations, design deliverable reviews (PFDs, P&IDs, 3D model, isometrics, reports), and verification dossiers.
I.6 Direct flow assurance and operability studies (OLGA/PIPESIM-based): hydrate/wax/asphaltene risks, slugging, transient shutdown/restart, start-up curves, and mitigation strategy selection.
I.7 Drive reliability/availability/maintainability (RAM) and sparing philosophy; ensure maintainability, accessibility, and isolation strategies are embedded in layout and design.
I.8 Champion safety in design and ALARP demonstrations; oversee QRA inputs, fire/explosion analysis, emergency shutdown/relief sizing, and Safety Instrumented Functions (SIF) verification.
I.9 Integrate engineering with project controls: define milestones, discipline deliverable registers, hold-point/witness plans, technical progress curves, and earned value traceability.
I.10 Constructability and marine operations: approve installation engineering (lift, seafastening, stability, moorings, DP capabilities), weather windows, and SIMOPS plans with marine and construction teams.
I.11 Commissioning and start-up readiness: systemization, pre-commissioning procedures (hydrotest, dewatering, drying, MEG), FAT/SAT/EFAT oversight, punch management, OR&A and PSSR closeout.
I.12 Technical risk management: maintain risk registers, lead value engineering, drive design-to-cost initiatives, and arbitrate trade-offs between CAPEX/OPEX vs. operability and risk.
I.13 Data and technical information management: master tag registers, engineering numbering, as-built redlines, technical data books, and digital handover to operations/CMMS.
I.14 Regulatory and stakeholder engagement: submissions for permits/class approvals; technical representation in audits, partners/joint ventures, and assurance gates (e.g., DG0–DG4 style).
I.15 People leadership: manage discipline leads, set priorities, balance workloads, approve manpower plans, and mentor senior/graduate engineers.
I.16 Budget and VOWD stewardship on technical scope; support change orders, claims defense/substantiation, and negotiation from a technical basis.

Key technical KPIs and formulas used

I.KPI.1 Availability: \( A = \frac{\text{MTBF}}{\text{MTBF} + \text{MTTR}} \)
I.KPI.2 EVM: \( \text{SPI} = \frac{EV}{PV},\quad \text{CPI} = \frac{EV}{AC} \)
I.KPI.3 Risk scoring: \( R = P \times C \)
I.KPI.4 Value assessment (VE/alternative selection): \( \text{NPV} = \sum_{t=0}^{n} \frac{CF_t}{(1+r)^t} \)

II. Required Skills and Demands

II.A Technical skills

II.A.1 Deep understanding of offshore systems: SURF, subsea production, subsea power/controls, topsides process, structural/marine, electrical and instrumentation, and automation.
II.A.2 Competence in technical assurance: HAZOP/LOPA/SIL, QRA interpretation, functional safety, relief and flare systems, and hazardous area classification.
II.A.3 Flow assurance, hydraulics, thermal management, and transient operations; familiarity with hydrate and wax control methods.
II.A.4 Installation and marine operations engineering awareness: lifting, seafastening, mooring, stability, and DP limitations.
II.A.5 RAM modeling, maintenance strategies, spares philosophy, and CMMS integration for reliability-centered maintenance.
II.A.6 Project controls literacy: scope definition, WBS, EVMS interpretation, and change control.
II.A.7 Standards and codes: API 17/ RP 2 series, ASME B31.3/B31.4/B31.8, ISO 13628/19901, DNV pipeline/structural codes, class rules.

II.B Soft skills

II.B.1 Leadership under schedule and weather-window pressure; decisive risk-based decision-making.
II.B.2 Interface management and stakeholder alignment across contractors, regulators, partners, and operations.
II.B.3 Negotiation and conflict resolution on technical scope, variations, and claims.
II.B.4 Clear technical writing and presentation for gate reviews, management, and assurance bodies.
II.B.5 Coaching and talent development for multi-discipline teams.

II.C Certifications and physical demands

II.C.1 Offshore survival and helicopter training (e.g., BOSIET/HUET) and valid medical; mandatory for site/vessel visits.
II.C.2 Ability to work at height and in confined spaces during inspections; tolerate vessel motion and climb ladders/stairs in PPE.
II.C.3 Desirable: PMP/chartership/licensure, functional safety certification (e.g., TÜV for SIL), lifting/rigging awareness.

III. Typical Tools, Software, and Equipment

III.1 Project and portfolio management: Primavera P6, MS Project, risk registers (active risk tools), EVMS dashboards.
III.2 Engineering and simulation oversight: AVEVA E3D/PDMS, Smart 3D, Navisworks; ANSYS/Abaqus (FEA); SACS (jacket); OrcaFlex/Offpipe (installation); HYSYS/Unisim (process); OLGA/PIPESIM (flow assurance); Caesar II (stress); ETAP (power systems).
III.3 Technical assurance and safety: HAZOP/LOPA/SIL tools, QRA software, fire/explosion modeling tools.
III.4 Data/document control: Aconex, SharePoint/EDMS, tag/drawing management, action tracking systems.
III.5 Commissioning and CMMS: Completions systems (e.g., CCS/WinPCS equivalents), SAP PM/Maximo for asset data and spares, punch-list tools.
III.6 Field and marine equipment (oversight): DP2/DP3 construction vessels, pipelay/j-lay towers, heavy-lift cranes, ROVs, test pumps, hydrotest/dewatering spreads, drying/N2/MEG units, metrology systems.
III.7 Analytics and reporting: BI dashboards for KPIs, cost/schedule integration, RAM analysis tools.

IV. Work Environment

IV.1 Primarily office-based (engineering/PMT), with frequent yard, fabrication, and vessel/offshore site visits during installation/commissioning.
IV.2 Offshore rotations for critical activities may follow 14/14 or 28/28 while remaining staff may use business-travel rotations; long shifts during weather windows are common.
IV.3 Global travel 25–50% during EPCI phases; intensified presence during FAT/SAT, load-out, hook-up, and start-up.
IV.4 Strict HSE and marine safety adherence; SIMOPS constraints, weather/sea-state limits, and permit-to-work systems.

V. Reporting Lines and Cross-Functional Interfaces

V.1 Reports to: Project Manager/Project Director (development phase) or Asset/Operations Manager (late commissioning and handover).
V.2 Direct reports: Discipline Lead Engineers (process, subsea/SURF, structural, mechanical/piping, electrical, instrumentation/controls, flow assurance), Interface Manager, Technical Assurance Lead, Engineering Coordinators.
V.3 Key interfaces: HSE, Quality, Project Controls, Supply Chain/Contracts, Fabrication/Construction, Marine/Installation, Drilling & Completions, Operations/Maintenance, Metocean/Survey, Regulatory/Classification, Partners/JV technical committees, Commissioning/Start-up.
V.4 External: EPCI contractors, design houses, equipment vendors, verification bodies, certifying authorities, classification societies, and regulators.

VI. Career Ladder

VI.1 Next-step roles: Senior Technical Manager, Engineering Manager, Project Manager, Asset/Operations Manager, Technical/Projects Director.
VI.2 To advance: Deliver multiple FEED-to-start-up projects with strong HSE/quality outcomes; demonstrate budget/schedule control, successful commissioning/handover, team development, and robust stakeholder management. Strengthen credentials (PMP/chartership, functional safety, lifting authority, RAM specialization).
VI.3 Broadened exposure: Deepwater subsea tiebacks, floating production, electrification/power-from-shore, brownfield debottlenecking, and decommissioning.

VII. Deliverables & Interfaces

VII.1 Key deliverables owned/approved: Basis of Design, Engineering Management Plan, Technical Assurance Plan, Interface Management Plan, HSE Philosophy and Safety Case inputs, discipline design deliverables (approval/acceptance), RAM and flow assurance reports, installation engineering approvals, commissioning plans/systemization, data books, as-built dossiers, handover packages (including asset tags, spares, CMMS data), MOC/TQ/NCR/Concession logs.
VII.2 Handoffs: To Construction/Installation (IFC deliverables, method statements), to Commissioning (pre-commissioning dossiers, test packs), to Operations (operating manuals, cause & effect, SIF proof-test plans, CMMS-ready data), to Project Controls (progress curves, EV inputs), to Supply Chain (technical bid tabs).
VII.3 Reporting cadence: Weekly progress to PM, monthly management reports, gate review packs at decision gates, readiness reviews (ORR/PSSR) before start-up.

VIII. Toolchain Snapshot

VIII.1 Planning/Controls: Primavera P6, MS Project, EV dashboards, risk tools.
VIII.2 Engineering: AVEVA E3D/PDMS, Smart 3D, SACS, ANSYS/Abaqus, OrcaFlex, Caesar II, ETAP, HYSYS/Unisim, OLGA/PIPESIM.
VIII.3 Assurance/Safety: HAZOP/LOPA/SIL tools, QRA and fire/explosion modeling applications.
VIII.4 Information management: EDMS (Aconex/SharePoint equivalents), completions systems, SAP PM/Maximo.
VIII.5 Field execution (oversight): ROVs, lifting gear inspection/NDT gauges, hydrotest/dewatering/drying packages, metrology and survey systems.

IX. Progression Trigger

IX.1 Typically promoted after: 2–3 executed EPCI projects or 1 full-cycle greenfield from FEED to start-up, with zero LTI on technical scope, =5% variance to AFE on technical deliverables, and successful ORR/PSSR closeouts.
IX.2 Reinforcing credentials: PMP or equivalent, chartered/professional engineer status, functional safety certification (SIL), and demonstrable RAM/flow assurance leadership on at least one deepwater or complex brownfield SIMOPS project.
IX.3 Peer/assurance endorsements: Positive independent verification and partner technical committee reviews on technical assurance and compliance.