What does a project manager do in oilfield operations?

I. Core Responsibilities

• I.1 Plan and approve integrated project baselines (scope, WBS, schedule, cost, risk, quality) for oilfield campaigns (drilling/completions, workovers, pads, pipelines, tank batteries, and tie-ins).
• I.2 Lead daily operations calls; coordinate SIMOPS across rigs, completions spreads, construction crews, and production operations.
• I.3 Own HSE leadership: verify permit-to-work, JHAs, barrier management, and stop-work authority; track TRIR and high-potential events.
• I.4 Control scope and MoC; validate AFEs; administer contract variations, claims, and change orders.
• I.5 Manage schedule using critical path and resource leveling; remove constraints (materials, personnel, logistics, approvals).
• I.6 Oversee cost control and earned value; approve accruals, commitments, and progress certificates; reconcile with ERP actuals.
• I.7 Direct procurement strategy (lump-sum, unit-rate, day-rate, performance-based); set KPIs and SLAs for contractors and service companies.
• I.8 Coordinate logistics: rig moves, heavy lifts, marine/aviation, last-mile access, seasonal windows, and weather downtime contingencies.
• I.9 Govern technical interfaces between subsurface, drilling, completions, facilities, production, and integrity teams; steward interface registers.
• I.10 Assure quality: ITPs, FAT/SAT, welding/NDT, hydrotests, function tests, and commissioning punchlist management (A/B/C).
• I.11 Drive NPT reduction: root-cause analysis, corrective actions, lessons learned integration into programs and procedures.
• I.12 Maintain regulatory compliance: permits, consents, environmental controls, and reporting to authorities.
• I.13 Manage stakeholder communications: internal leadership, field supervisors, contractors, landowners/communities for access and impacts.
• I.14 Execute start-up and handover: pre-startup safety reviews, readiness checklists, performance tests, and handover to operations/maintenance.
• I.15 Report performance: progress S-curves, cost/schedule forecasts, risk heat maps, and dashboard updates to governance forums.
• I.16 Coach field leaders; ensure competency matrices and crew readiness for campaign phases.

Key Operating Metrics and Formulas

• I.A Earned Value: \( \textbf{SPI} = \frac{EV}{PV} \), \( \textbf{CPI} = \frac{EV}{AC} \), \( \textbf{EAC} = \frac{BAC}{CPI} \), \( \textbf{ETC} = EAC - AC \)
• I.B Non-Productive Time: \( \textbf{NPT\%} = \frac{\text{NPT hours}}{\text{Total operational hours}} \times 100\% \)
• I.C Safety: \( \textbf{TRIR} = \frac{\text{Recordable cases} \times 200{,}000}{\text{Total work-hours}} \)
• I.D Risk Exposure: \( \textbf{Expected\ Risk} = \sum (P_i \times I_i) \); Contingency via Monte Carlo on cost/schedule drivers.

II. Required Skills and Physical Demands

Technical Skills

• II.1 Oilfield project controls: WBS, EVMS, AFE stewardship, change control, cashflow and accruals.
• II.2 Scheduling: critical path, resource-constrained schedules, what-if scenarios for rig/completion spreads.
• II.3 Drilling/Completions literacy: well programs, BHA, fluids, pressure control, frac stages, flowback, and well integrity.
• II.4 Facilities/Construction literacy: pads, separators, tanks, LACT units, pipelines, pigging, electrical/ICA, and commissioning.
• II.5 HSE systems: barrier models, SIMOPS, LOTO, confined space, lifting plans, and process safety basics.
• II.6 Contracts & procurement: day-rate vs. turnkey, unit price schedules, performance incentives, claims/LDs.
• II.7 Risk management: qualitative/quantitative analysis, schedule and cost risk, MoC governance.
• II.8 Data and reporting: KPI dashboards, variance analysis, field data reconciliation.

Soft Skills

• II.9 Leadership under pressure; clear decision-making and conflict resolution across multi-company teams.
• II.10 Stakeholder alignment and negotiation; concise briefings for executives and regulators.
• II.11 Structured problem-solving; root-cause and corrective action discipline.
• II.12 Cultural and field-savvy communication; safety-first mindset.

Physical Demands

• II.13 Regular site visits; climbing stairs and ladders on rigs/facilities; PPE use in all weather.
• II.14 Offshore/remote travel; ability to pass HUET/seasurvival/medical as required.
• II.15 Extended hours during critical operations, call-out availability for incidents.

III. Typical Tools, Software, and Equipment

• III.1 Scheduling: Primavera P6, Microsoft Project.
• III.2 Cost/ERP: SAP or Oracle ERP; cost control spreadsheets; AFE and commitment tracking tools.
• III.3 Risk: Primavera Risk Analysis, @RISK (Monte Carlo), bowtie tools.
• III.4 Reporting/BI: Power BI or Tableau; dashboarding; S-curves.
• III.5 Field reporting: WellView/OpenWells, morning report systems, digital work permits, e-PTW.
• III.6 Document control: Aconex, SharePoint, controlled transmittals, and redline/as-built workflows.
• III.7 CMMS: Maximo or equivalent for handover to operations/maintenance.
• III.8 Engineering/Design review: AutoCAD, Navisworks, P&ID viewers; GIS tools (e.g., ArcGIS/QGIS) for routing/access.
• III.9 HSE: incident management systems, gas detectors, lifting/rigging inspection registers.
• III.10 Communications: VHF/UHF radios, satellite comms, rig-site video for remote support.

IV. Work Environment

• IV.1 Onshore office base with frequent field presence (rigs, frac sites, construction spreads, plants).
• IV.2 Offshore campaigns as required; site rotations during critical execution windows.
• IV.3 Typical schedule: office 5–2; during execution peaks may shift to 14–14, 21–21, or 28–28 to align with site rhythms.
• IV.4 Travel: 25–50% common; higher in early construction/commissioning or multi-rig programs.
• IV.5 Exposure to remote logistics, harsh climates, and SIMOPS; strict adherence to HSE protocols.

V. Reporting Lines and Cross-Functional Interfaces

• V.1 Reports to: Operations Manager – Oilfield Projects or Project Director – Oilfield Operations.
• V.2 Direct reports: project engineers, planners/schedulers, cost controllers, document controllers, construction supervisors, commissioning leads.
• V.3 Key interfaces: drilling and completions superintendents, production/operations, facilities/engineering, subsurface, HSE, supply chain, logistics, finance, land/legal, regulatory.
• V.4 External: rig contractors, service companies, EPC/Construction contractors, OEMs, surveyors/inspectors, certification bodies, community/land access stakeholders.

VI. Career Ladder

• VI.1 Next roles: Senior Project Manager – Oilfield Operations; Project Director – Oilfield Operations; Asset Project Manager – Oilfield Operations.
• VI.2 Requirements to move up:
  • Delivery of 2–3 full-cycle field execution projects (e.g., multi-well pad or pipeline/facilities expansions) = USD 50–200 million with strong HSE and EV performance.
  • Consistent CPI = 0.95 and SPI = 0.95 at closeout; demonstrated NPT reduction and start-up on spec.
  • Advanced certifications: PMP or equivalent; formal HSE leadership; incident command; contract management.
  • Proven leadership of multi-discipline teams across drilling/completions and facilities interfaces.

VII. Deliverables & Interfaces

• VII.1 Deliverables:
  • Project Execution Plan, HSE Plan, and Interface Management Plan.
  • Approved schedule (Level 3/4), cost baseline, risk register, and contingency model.
  • Contracting strategy, tender docs, bid evaluations, award recommendations.
  • Daily/weekly progress reports, EV dashboards, and management presentations.
  • Quality dossiers, redlines/as-builts, commissioning certificates, and operations handover package.
  • Closeout report with lessons learned and performance benchmarking.
• VII.2 Interfaces:
  • Upward: Operations Manager/Project Director (governance, approvals, performance).
  • Lateral: discipline leads (drilling, completions, production, facilities, HSE, SCM, finance).
  • Downward: supervisors, contractors, and vendors executing field tasks.
  • External: regulators, inspectors, certifiers for permits and acceptance.

VIII. Toolchain Snapshot

• VIII.1 Planning/Controls: Primavera P6; Microsoft Project; cost control workbooks; EV dashboards.
• VIII.2 ERP/CMMS: SAP/Oracle; Maximo.
• VIII.3 Risk/QA: Primavera Risk Analysis; @RISK; bowtie; ITP and punchlist systems.
• VIII.4 Field/Reporting: WellView/OpenWells; e-PTW; Power BI/Tableau.
• VIII.5 Eng/Docs: AutoCAD/Navisworks; GIS; Aconex/SharePoint.
• VIII.6 HSE/Comms: incident reporting tools; gas detection; radios/satellite comms.

IX. Progression Trigger

Typically promoted after 3–5 years in role with delivery of = 2 major oilfield operations projects (multi-rig or multi-pad program) meeting HSE targets (zero LTI), CPI/SPI = 0.95, successful commissioning/start-up, plus certification such as PMP and completion of formal HSE leadership and contracts management training.