Job description for a planning engineer in oilfield operations?

Planning Engineer — Oilfield Operations

Responsible for building, optimizing, and governing integrated plans and schedules for oilfield operations across drilling, completions, workovers, logistics, and production support, ensuring safe, efficient, and cost-controlled execution.

I. Core Responsibilities

• I.1 Develop and maintain integrated Level 1–5 schedules (CPM-based) for drilling, completions, well interventions, pad moves, logistics, and SIMOPS.
• I.2 Build and manage rig and spread line-ups; optimize sequence to minimize non-productive time, rig idle, and mobilization/demobilization costs.
• I.3 Establish Work Breakdown Structure (WBS), coding structures, calendars, and resource dictionaries aligned with corporate standards and cost structures.
• I.4 Execute critical path analysis, resource loading/leveling, and what-if scenarios to test constraints (permits, pad readiness, land access, POB, marine/aviation windows).
• I.5 Lead 1–2 week, 13-week, and annual look-ahead planning cycles; chair planning meetings; capture actions and decisions for schedule updates.
• I.6 Coordinate long-lead materials and services planning with supply chain; align RFQs, call-offs, and delivery dates to schedule need-by dates.
• I.7 Govern change control and re-baselining; quantify schedule impacts of scope changes, weather, logistics delays, and contractor performance.
• I.8 Track actuals and progress; produce S-curves, histograms, and dashboards; report KPIs (SPI, CPI, variance) and recovery plans.
• I.9 Interface with subsurface, drilling, completions, production operations, HSE, logistics, marine/aviation, and contractors to resolve conflicts and SIMOPS clashes.
• I.10 Run probabilistic schedule risk analysis (estimated) and generate P-50/P-80 dates; advise on contingency and buffers.
• I.11 Plan shutdown/turnaround windows and major interventions; align multi-discipline execution sequences and isolation/permit schedules.
• I.12 Ensure data quality and governance: progress measurement rules of credit, actuals capture, coding discipline, and auditability.
• I.13 Compile lessons learned and continuous improvement actions to reduce cycle time and elevate plan fidelity.

Key Planning Formulas and Methods

• I.A Critical Path Method (CPM): Total Float \(TF = LS - ES = LF - EF\); critical path where \(TF = 0\).
• I.B Earned Value Management (EVM): \(SPI = \frac{EV}{PV}\), \(CPI = \frac{EV}{AC}\), \(EAC \approx \frac{BAC}{CPI}\) or \(EAC = AC + \frac{BAC - EV}{CPI}\).
• I.C People on Board (POB) constraint: \(\sum_i POB_i(t) \leq \text{Bed Capacity}\) across SIMOPS time slices.
• I.D Weather/marine window constraint (estimated): \(P(\text{operable}) = \prod_t P(H_s \leq H_{lim}, U \leq U_{lim})\) for task duration.

II. Required Skills and Physical Demands

• II.1 Technical Skills
  • Expert CPM scheduling; resource loading/leveling; S-curve and histogram development.
  • EVM, cost/schedule integration; AFE awareness and cashflow phasing.
  • Oilfield operations sequencing: spud-to-release, frac/flowback, coil/tubing, wireline, workover, well test, SIMOPS.
  • Constraint management: permits, pad/site readiness, well access, POB, lifting, marine/aviation slots.
  • Risk analysis (deterministic/probabilistic), buffers, and contingency planning (estimated).
  • Data modeling and analytics: advanced Excel; data joins across ERP, drilling reports, and timesheets.
  • Standards: WBS/coding, calendar logic, progress rules of credit, change control governance.
  • HSE and PTW scheduling awareness; isolation and simultaneous operations constraints.
• II.2 Soft Skills
  • Clear, assertive communicator; meeting facilitation and conflict resolution.
  • Stakeholder management across disciplines and contractors.
  • Analytical rigor, attention to detail, data integrity mindset.
  • Scenario thinking; agility under changing priorities; decision framing.
• II.3 Physical/Certifications (estimated)
  • Periodic field/offshore site visits; ability to use standard PPE, climb stairs/ladders, and traverse uneven ground.
  • May require offshore survival/medical certification for occasional platform/rig access.
  • Extended screen time; tight deadlines around schedule cut-offs and look-ahead cycles.

III. Typical Tools, Software, and Equipment

• III.1 Scheduling/Risk: Primavera P6, Microsoft Project; Primavera Risk Analysis or equivalent (estimated); Deltek Acumen Fuse/Risk (estimated).
• III.2 Analytics/Reporting: Excel (Power Query/Power Pivot), Power BI/Tableau; VBA or Python for data automation (estimated).
• III.3 Oilfield/Operations Data: Well engineering/planning interfaces (e.g., WellPlan, Compass, OpenWells/EDR); maintenance/operations CMMS (SAP PM, Maximo); ERP (SAP/MM) for materials alignment.
• III.4 Collaboration/Docs: SharePoint/Teams; action trackers; document control systems.
• III.5 Field/Logistics: POB/manifest tools, marine/aviation scheduling systems (estimated), GPS/GIS for access/route planning (ArcGIS/QGIS, estimated).
• III.6 Equipment: Laptop with multiple displays; intrinsically safe mobile device for site; standard PPE; radios where required.

Toolchain Snapshot

• Primavera P6, MS Project, Acumen, Primavera Risk Analysis.
• Excel + Power BI/Tableau; SharePoint/Teams.
• SAP PM/MM or Maximo; drilling reporting interfaces (OpenWells/EDR).
• POB/manifest and marine/aviation schedulers (estimated).

IV. Work Environment

• IV.1 Location: Primarily office-based at onshore operations/asset center; embedded with drilling/completions/operations teams.
• IV.2 Field Exposure (estimated): Short-duration site visits to rigs, pads, platforms, supply bases, yards for planning walkdowns and readiness checks.
• IV.3 Schedule: Standard 5/2 workweek with periodic evening/weekend cut-offs for schedule updates; during campaigns, increased cadence around look-ahead meetings.
• IV.4 Travel: 10–30% travel depending on asset maturity and campaign intensity; occasional offshore/remote travel subject to certification.
• IV.5 Environment: Multi-disciplinary, deadline-driven; concurrent projects; high coordination load across contractors and internal functions.

V. Reporting Lines and Cross-Functional Interfaces

• V.1 Reporting To: Operations Planning Manager, Drilling & Completions Manager, or Asset Manager (organization-dependent).
• V.2 Direct Interfaces:
  • Drilling, completions, and well services engineers and superintendents.
  • Subsurface (geology, geophysics, reservoir) for well sequencing/readiness.
  • Production operations, maintenance, and reliability for shutdowns/SIMOPS.
  • HSE and PTW coordinators for isolations, lifting plans, and concurrent operations controls.
  • Supply chain/materials, warehouse, and logistics (land, marine, aviation).
  • Finance/project controls for EVM and cashflow alignment.
  • Contractors: drilling contractors, frac/coiled tubing/wireline/service companies, marine/aviation providers.
  • Land/legal/community relations for access and permitting gates.

Deliverables & Interfaces

• Primary Deliverables: Integrated Activity Plan, L1–L5 schedules, rig/spread line-ups, 13-week look-ahead, S-curves, resource histograms, POB forecasts, SIMOPS matrices, readiness checklists, change logs, and monthly planning reports.
• Handoffs:
  • To drilling/completions superintendents: executable look-ahead plans, permits/materials readiness gates, and sequence constraints.
  • To logistics/marine/aviation: manifests, sail/flight plans, and berth/heli-slot windows tied to schedule.
  • To supply chain: demand signals, required-on-site dates, and call-off timing.
  • To finance/project controls: progress, variances, SPI/CPI, and EAC updates for monthly closes.
  • To HSE/PTW: SIMOPS overlays, isolation timing, and lifting/critical task windows.

VI. Career Ladder

• VI.1 Next-Step Roles: Senior Planning Engineer, Lead Integrated Activity Planner, Asset Planning Lead, Operations Planning Manager.
• VI.2 Longer-Term Pathways: Asset Manager, Drilling/Completions Performance Manager, Operations Excellence Manager, Project Controls/Portfolio Manager.
• VI.3 Advancement Requirements (estimated):
  • Demonstrated delivery of multiple campaigns (e.g., 3–5 multi-well programs or a full-year asset plan) with high plan adherence and sustained SPI ˜ 0.95–1.05.
  • Leadership of cross-functional planning forums and successful resolution of SIMOPS conflicts.
  • Tool mastery (Primavera P6 expert level) and data automation/reporting capability.
  • Certifications: PMI-SP or PMP; Primavera P6 practitioner; offshore survival (if offshore exposure required).

Progression Trigger

Typically promoted after completing 2–3 annual planning cycles or 18–36 months of sustained performance, plus certification (PMI-SP or PMP) and evidence of leading integrated planning with measurable efficiency gains (estimated).