Responsibilities of a commissioning manager in oilfield operations?

Commissioning Manager (Oilfield Operations)

Accountable for planning, leading, and assuring safe, efficient pre-commissioning, commissioning, and start-up of oilfield facilities and systems until formal handover to Operations.

I. Core Responsibilities

1. 1. Systems Completion Management
   • 1.1 Define systemization and sub-system breakdown aligned to P&IDs, single line diagrams, and control narratives.
   • 1.2 Build and govern the completions database, tagging, and certification hierarchy (A/B/C punch, RFC/RFSU/RFO).
   • 1.3 Develop and enforce the Systems Completion Plan, ITPs, check sheets, and turnover dossiers.
2. 2. Commissioning Strategy and Planning
   • 2.1 Author the Commissioning Execution Plan, organization charts, manpower curves, SIMOPS matrix, and CSU schedule.
   • 2.2 Define preserves, energization strategy, discipline sequence (MECH ? E&I ? Controls ? Process), and spares/consumables.
   • 2.3 Lead readiness gates: MC, RFC, RFSU, PSSR, and performance test acceptance.
3. 3. HSSE and Risk Control
   • 3.1 Own PTW, LOTO, isolations, MoC, and SIMOPS risk register; steward HAZOP/LOPA/HAZID action close-out.
   • 3.2 Chair daily toolbox talks, pre-start reviews, and incident learning; ensure compliance with regulatory permits.
4. 4. Pre-commissioning and Functional Testing
   • 4.1 Direct cleaning, gauging, chemical cleaning, pickling, passivation, air blowing, oil flushing (turbulent), and drying.
   • 4.2 Oversee pressure tests, leak tests (nitrogen/helium), tightness testing, and reinstatement management.
   • 4.3 Execute loop checks, instrument calibration, cause-and-effect testing, and shutdown hierarchy validation.
5. 5. Energization and Start-up
   • 5.1 Authorize HV/LV, pneumatic, and hydraulic energization; verify switchgear, MCCs, UPS, and earthing integrity.
   • 5.2 Manage inerting/purging, first oil/gas-in, rotating equipment run-in, flare/BDV testing, and ESD/F&G integration.
   • 5.3 Lead performance, reliability and availability (R&A) trials, and capacity/efficiency tests to acceptance criteria.
6. 6. Interfaces, Handover, and Operability
   • 6.1 Coordinate with Construction for MC, punch closure, red-line markups, and as-built updates.
   • 6.2 Prepare Turnover Packages, O&M manuals, CMMS master data, critical spares lists, and preservation release.
   • 6.3 Deliver operator training/OJT, start-up procedures, alarm rationalization, and handover to the Asset.
7. 7. Project Controls and Vendor Management
   • 7.1 Own CSU budget, schedule (L2/L3), progress curves, and KPI dashboards (system RFC rate, punch burn-down, TRIR).
   • 7.2 Plan vendor interventions, SATs, factory reps, and warranty acceptance; negotiate scope/time variations.

II. Required Skills and Physical Demands

1. 1. Technical Skills
   • 1.1 Systems completion methodology, CSU workpacks, and turnover management.
   • 1.2 Process, mechanical, E&I, and controls integration; cause-and-effect matrices; SIL/functional safety awareness.
   • 1.3 Pressure testing, leak testing, inerting/purging, oil flushing, hydrocarbon handling, flare/vent systems.
   • 1.4 HV/LV commissioning, MCCs, drives, generators, UPS, grounding, and earthing tests.
   • 1.5 DCS/PLC/ESD/F&G loop checks, logic validation, and alarm rationalization.
   • 1.6 Rotating equipment run-in, alignment, vibration/balancing, lube system commissioning.
   • 1.7 CMMS data build (tags, PMs, BOMs), critical spares strategy, and preservation release.
   • 1.8 PTW/SIMOPS, MoC, and regulatory compliance for start-up and emissions/discharges.
2. 2. Soft Skills
   • 2.1 Leadership under time pressure; decision-making in dynamic, risk-laden environments.
   • 2.2 Interface management across EPC, vendors, and Operations; conflict resolution.
   • 2.3 Planning and controls: schedule integration, progress measurement, and reporting.
   • 2.4 Communication: concise shift handovers, punchlist prioritization, and permit briefings.
3. 3. Physical Demands
   • 3.1 Frequent field presence; climbing, confined spaces, and working at heights.
   • 3.2 Offshore transfers, vibration/noise exposure, and extended shifts during start-up.
   • 3.3 PPE use in hydrocarbon areas; H2S environments and extreme temperatures.

III. Typical Tools, Software, and Equipment

1. 1. Systems Completion & Controls
   • 1.1 Systems completion databases (ICAPS/WinPCS/PIMS).
   • 1.2 DCS/PLC/ESD/F&G engineering stations; historian/trend tools.
   • 1.3 Loop test tools: HART/field communicators, signal simulators, multifunction calibrators.
2. 2. Mechanical and Process Commissioning
   • 2.1 Pressure test units, deadweight testers, nitrogen/helium leak testing skids.
   • 2.2 Oil flushing skids, high-volume air blowers, dryers, and dew point analyzers.
   • 2.3 Vibration analyzers, laser alignment tools, borescopes.
3. 3. Electrical & Safety
   • 3.1 Meggers, hipot testers, relay test sets, primary injection kits.
   • 3.2 Portable gas detectors (LEL/O2/H2S), fire & gas test equipment.
   • 3.3 LOTO equipment, insulated tools, thermal imagers.
4. 4. Project Controls & Documentation
   • 4.1 CMMS (SAP PM/Maximo), permit-to-work systems, MoC tools.
   • 4.2 2D/3D model viewers and markup tools for P&IDs, SLDs, and as-builts.
   • 4.3 Reporting dashboards, progress trackers, and punchlist management tools.

IV. Work Environment

1. 1. Locations
   • 1.1 Onshore: well pads, flowlines, gathering systems, central processing facilities, terminals.
   • 1.2 Offshore: platforms, FPSOs, subsea tie-backs, compression/water-injection modules.
2. 2. Shifts and Rotations
   • 2.1 Onshore projects: standard workweeks with surge to 6–7 days during start-up.
   • 2.2 Offshore: typical 14/14, 21/21, or 28/28 rotations; night shifts during critical windows.
3. 3. Travel and Field Time
   • 3.1 25–75% travel, with extended on-site presence in commissioning phases.
   • 3.2 Frequent vendor/site interface trips and readiness audits.
4. 4. Conditions
   • 4.1 SIMOPS with construction and early operations; strict PTW and exclusion zones.
   • 4.2 Noise, vibration, and hydrocarbon exposure; elevated/over-water work.

V. Reporting Lines and Cross-Functional Interfaces

1. 1. Reporting Lines
   • 1.1 Reports to: Project Manager (project phase) or Operations/Asset Manager (late CSU/start-up).
   • 1.2 Direct reports: Systems Completion Lead, Discipline Commissioning Leads (Process, Mechanical, E&I, Controls), PTW Coordinator, Preservation Lead, Document/Completions Controllers.
2. 2. Cross-Functional Interfaces
   • 2.1 Construction/QAQC: MC, punch closure, weld/NDT records, reinstatement.
   • 2.2 Operations/Maintenance: CMMS data, procedures, training, and handover.
   • 2.3 HSE: SIMOPS, PTW, emergency response readiness, regulatory permits.
   • 2.4 Engineering: design queries, red-lines, as-builts, vendor technical clarifications.
   • 2.5 Subsurface/Drilling/Well Services: well tie-in windows, fluids-in coordination, shutdown planning.
   • 2.6 Vendors/OEMs/Certifiers: SATs, warranties, classifications/certifications (as applicable).

VI. Career Ladder and Progression

1. 1. Next-Step Roles
   • 1.1 Start-Up Manager / CSU Director (multi-asset responsibility).
   • 1.2 Project Manager (EPC/EPCC) or Operations/Asset Manager (brownfield/greenfield ramp-up).
   • 1.3 Systems Completion Manager / OR&A Manager / Commissioning Advisor.
2. 2. What’s Needed to Move Up
   • 2.1 Track record on 2–3 major start-ups or 4–6 complex brownfield campaigns with zero LTI and on-schedule RFSU.
   • 2.2 Advanced competencies: SIMOPS leadership, functional safety, high-voltage switching authorization.
   • 2.3 Certifications: PMP (or equivalent), Functional Safety Engineer (TÜV or equivalent), CompEx/IECEx (Ex01–04), BOSIET/FOET (offshore), NEBOSH/IOSH (HSE), PTW Controller authorization.
   • 2.4 CMMS/OR&A data readiness leadership; vendor warranty and claims management experience.