Responsibilities of a well site supervisor in oil operations?

Well Site Supervisor — Oil Operations

Frontline company representative at the rig/wellsite responsible for safe, compliant, and efficient execution of approved drilling, completion, workover, and intervention programs.

I. Core Responsibilities

• 1.1 Operational Leadership
  • I.I Execute the approved well program (drilling/completion/workover) and adapt within Management of Change limits.
  • I.II Lead pre-job briefings, toolbox talks, and permit-to-work issuance; verify job steps, barriers, and contingencies.
  • I.III Coordinate rig contractor, service companies, and logistics to meet daily objectives and AFE/time–depth plan.
  • I.IV Enforce well control standards; verify barrier envelopes before operations (mechanical, hydraulic, inflow).
  • I.V Validate critical calculations (mud weight, hydraulics, cement volumes, string weights, torque/drag, pressure tests).
• 1.2 HSE and Compliance
  • I.VI Champion HSE policies; stop work if conditions are unsafe.
  • I.VII Ensure regulatory compliance, permit conditions, and adherence to company standards and bridging documents.
  • I.VIII Lead incident response, notifications, and initial investigations; drive corrective and preventive actions.
  • I.IX Verify hazardous area classification and safe systems of work (LOTO, confined space, hot work, dropped objects).
• 1.3 Execution Control and QA/QC
  • I.X Approve critical lift plans and pressure test charts; witness and sign off on function/pressure tests.
  • I.XI Audit service equipment certifications, calibration, and personnel qualifications before use.
  • I.XII Oversee QA/QC of tubulars, BHA, cement, fluids, and chemicals (receiving, traceability, usage).
  • I.XIII Manage drilling/completion fluids properties to program targets; troubleshoot trends in solids, rheology, contamination.
• 1.4 Daily Planning, Reporting, and Cost Control
  • I.XIV Conduct daily operations meetings and 24-hour look-ahead planning with all parties.
  • I.XV Maintain the Daily Drilling/Completion Report, time breakdown, operational narrations, lessons learned.
  • I.XVI Track NPT/ILT, flat time, performance curves; monitor AFE vs. actual cost and service ticketing.
  • I.XVII Reconcile materials usage and inventory; raise call-offs and backloads to optimize logistics.
• 1.5 Well Integrity and Control
  • I.XVIII Verify BOP and well control equipment readiness; ensure drills are performed to standard.
  • I.XIX Monitor kicks/losses indicators; direct shut-in and initial kill sheet preparation when required.
  • I.XX Validate pressure test schedules, barrier acceptance criteria, inflow tests, and suspension/abandonment steps.
• 1.6 Interface and Stakeholder Management
  • I.XXI Serve as single-point site contact to onshore operations, subsurface, drilling/completions engineering, HSE, logistics.
  • I.XXII Communicate status, risks, and decisions; escalate deviations and seek waivers per governance.
• 1.7 Operational Calculations (frequently validated on site)
  • I.XXIII Non-Productive Time: \( \text{NPT\%} = \dfrac{\text{NPT hours}}{\text{Total Operating hours}} \times 100\% \)
  • I.XXIV Kill Weight Mud: \( \text{KWM} = \text{MW}_{\text{current}} + \dfrac{\text{SIDPP}}{0.052 \times \text{TVD}} \)
  • I.XXV Maximum Allowable Annular Surface Pressure (at shoe): \( \text{MAASP} = (\text{FG}_{\text{shoe}} - \text{EMW}) \times 0.052 \times \text{TVD}_{\text{shoe}} \)
  • I.XXVI Cement volume (lead/tail): \( V = \text{Annular Cap} \times \text{Interval Length} \times (1 + \text{Excess\%}) \)
  • I.XXVII ECD at bit (ppg): \( \text{ECD} = \text{MW} + \dfrac{\Delta P_{\text{annulus}}}{0.052 \times \text{TVD}} \)

II. Required Skills and Demands

• 2.1 Technical Skills
  • II.I Well control proficiency (surface/subsea BOP); kick detection and initial response leadership.
  • II.II Drilling/completions/workover operations knowledge (BHAs, MPD basics, fishing, cementing, perforating, TCP/wireline/slickline/coiled tubing).
  • II.III Fluids engineering basics (density, rheology, ECD management, losses/LCM strategies).
  • II.IV Pressure testing and barrier verification; understanding LOT/XLOT, FIT, inflow tests.
  • II.V Reading well schematics, tubular tallies, torque/drag, hydraulics, and cement job design outputs.
  • II.VI Rig systems and equipment (draw-works, top drive, mud pumps, BOP control, HP/HT considerations).
  • II.VII QA/QC of critical services; recognition of equipment certification and calibration requirements.
  • II.VIII Cost/time analysis (AFE tracking, critical path, NPT categorization, performance benchmarking).
• 2.2 Soft Skills
  • II.IX Leadership under pressure; clear decision-making and calm incident command.
  • II.X Concise, bilingual/multilingual communication commonly required on international crews.
  • II.XI Conflict resolution, contractor management, and coaching for safe behaviors.
  • II.XII Planning and prioritization; disciplined documentation and handovers.
• 2.3 Physical and Site Demands
  • II.XIII Fit for duty for extended shifts; climb stairs/ladders, work in PPE, exposure to noise and weather.
  • II.XIV Ability to don emergency breathing apparatus; participate in drills and emergency response.
  • II.XV Offshore survival/sea-farer medicals or remote desert/Arctic readiness as applicable.

III. Tools, Software, and Equipment

• 3.1 Operations Control
  • III.I Rig instrumentation (pit volume totalizer, flow/out, hookload/torque/rotary RPM, standpipe pressure, ESD systems).
  • III.II BOP stacks and control systems (surface/subsea), choke/kill manifolds, accumulator units.
  • III.III Mud systems: shakers, centrifuges, desanders/desilters, mud pumps, mixing hoppers, density/viscosity instruments.
• 3.2 Digital and Reporting
  • III.IV Daily reporting platforms (WITSML-enabled DDR/DCR systems), time/cost tracking tools.
  • III.V Hydraulics and torque/drag checkers; cement job calculators; well control kill sheets.
  • III.VI Document control for permits, JSA, MOC, barrier logs, pressure test records.
• 3.3 Verification and QA/QC
  • III.VII Calibrated gauges and NDT reports; pressure test charts/recorders.
  • III.VIII Gas detection, H2S monitoring, breathing apparatus; confined space/atmosphere testing meters.

IV. Work Environment

• 4.1 Location
  • IV.I Offshore jack-up, semi-submersible, drillship, or fixed platform; onshore rigs (desert, jungle, arctic, remote pads).
• 4.2 Shifts/Rotations
  • IV.II Typical rotations: 14/14, 21/21, 28/28; 12-hour shifts with on-call responsibility 24/7.
  • IV.III Campaigns may extend to 30–90 days on multi-well pads or batch operations.
• 4.3 Travel and Logistics
  • IV.IV Helicopter or crew boat to offshore; 4×4 convoy or charter to remote land locations.
  • IV.V Pre-mobilization briefings; vendor/service crew schedules aligned to program needs.
• 4.4 Conditions
  • IV.VI Weather, sea state, and daylight constraints; potential H2S/HPHT or sour service environments.

V. Reporting Lines and Interfaces

• 5.1 Reporting Lines
  • V.I Reports to: Onshore Drilling/Completions Superintendent or Operations Manager.
  • V.II Functional support from: Drilling/Completions Engineers, HSE Advisor, Fluids/Cement Specialists.
• 5.2 Cross-Functional Interfaces
  • V.III Rig Contractor leadership (OIM/Toolpusher/Driller); Service Company supervisors (cementing, MW, wireline, CT, directional/MWD, solids control, fishing, well testing).
  • V.IV Subsurface (geology, geomechanics) for real-time decisions on casing points, mud weights, wellbore stability.
  • V.V Logistics/base, marine, aviation, warehousing, QA/QC inspectors.
  • V.VI Regulatory representatives and third-party verifiers when present.
• 5.3 Deliverables & Interfaces
  • V.VII Daily reports, time/cost tracking, barrier status, pressure test records, MOC logs ? to onshore operations and engineering.
  • V.VIII Job tickets, tally sheets, QA/QC documents, certification packs ? to procurement/contract/QA teams.
  • V.IX Lessons learned, end-of-well report inputs ? to engineering and performance teams.

VI. Career Ladder and Progression

• 6.1 Typical Path
  • VI.I Entry from: Driller/Toolpusher background or Field Supervisor (fluids/cement/coiled tubing/wireline) transitioning to company Well Site Supervisor.
  • VI.II Next roles: Senior Well Site Supervisor, Drilling/Completions Superintendent (onshore), Rigless Operations Superintendent, or Well Operations Manager.
• 6.2 What’s Needed to Move Up
  • VI.III Demonstrated delivery of wells within AFE and time–depth plan; reduced NPT% year-over-year.
  • VI.IV Strong safety leadership record; zero serious incidents; proven emergency response competence.
  • VI.V Mastery across well lifecycle (spud-to-TD, completions, workovers, interventions, P&A).
  • VI.VI Competence in complex environments (HPHT, deepwater, ERD, MPD, H2S sour service).
• 6.3 Progression Trigger
  • VI.VII Typically promoted after 8–12 complex wells or 18–24 months with documented performance KPIs, plus current well control certification (supervisor level) and barrier management competence sign-off.