Job description for a process engineer in oil and gas production?

Process Engineer — Oil and Gas Production

Designs, debottlenecks, and optimizes upstream production facilities (wellsite, gathering, separation, gas treating/dehydration, compression, stabilization, water handling). Ensures safe capacity, regulatory compliance, and operability from concept through operations support.

I. Core responsibilities (day-to-day)

• I.1 Develop and maintain PFDs, P&IDs, heat and material balances, line lists, and tie-in schedules for production facilities.
• I.2 Perform process simulations (steady-state/dynamic) for separation trains, compression, dehydration, sweetening, stabilization, and flaring/relief systems.
• I.3 Size equipment: separators, scrubbers, pumps, compressors, heat exchangers, dehydrators, columns, control valves, and relief devices per applicable codes.
• I.4 Execute hydraulic calculations: single- and multiphase pipelines/flowlines, flare networks, and facility piping (normal, startup, shutdown, blowdown).
• I.5 Author process datasheets, control narratives, shutdown keys, cause & effect matrices, alarm rationalization, and operating envelopes.
• I.6 Lead/participate in HAZID, HAZOP, LOPA, SIL determination; close actions and implement safeguards.
• I.7 Relief and flare system design: contingency identification, PSV sizing, scenario summation, dynamic verification, and flare radiation/noise checks.
• I.8 Flow assurance input: PVT characterization, hydrate/wax/asphaltene risk screening, injection/insulation setpoints, pigging philosophy.
• I.9 Support commissioning and startup: SAT/loop checks, first oil/gas ramp-up plans, performance testing, nameplate verification, trip testing.
• I.10 Troubleshoot plant upsets: bottleneck diagnosis, fouling/erosion, foaming, carry-over, slugging, cavitation, anti-surge events; define corrective actions.
• I.11 Optimize energy and chemicals: compression/pumping efficiency, heat integration, fuel gas balance, MEG/MDEA/glycol systems, FPSO utilities.
• I.12 Author MOCs and operating procedures; train operations on changes and alarm limits; update controlled documents.
• I.13 Regulatory and standards compliance: design basis, relief/flare dossiers, emissions, produced water quality, fiscal metering inputs.
• I.14 Vendor/EPC oversight: review calculations, drawings, FAT/SAT procedures, and performance guarantees; respond to RFIs/TQs.
• I.15 KPI tracking: throughput, recovery, availability, losses, flaring, energy intensity; set improvement targets and action plans.

II. Required skills and physical demands

II.A Technical skills

• II.A.1 Facility process design: separation, treating, compression, utilities, relief and blowdown, and shutdown philosophies.
• II.A.2 Simulation and modeling: steady-state and dynamic facility, network, and flare simulations; control loop dynamics.
• II.A.3 Codes & standards: API 14C/14J/14E, API 520/521/2000, ASME B31.3/VIII, ISO 10418, IEC 61511, NACE MR0175/ISO 15156, company specifications.
• II.A.4 Relief/flare: scenario development, PSV/BDV sizing, supercritical/gas relief, two-phase, built-up backpressure, radiation and dispersion checks.
• II.A.5 Flow assurance fundamentals: hydrate curves, wax appearance, slug control, thermal modeling, chemical inhibition, MEG regeneration/reclamation.
• II.A.6 Control and safeguarding: PID fundamentals, anti-surge control, compressor performance maps, ESD/PSD logic, trip matrix development.
• II.A.7 Materials and corrosion input: CO2/H2S corrosion drivers, erosion criteria, material selection envelope coordination with materials engineers.
• II.A.8 Calculations and formulas (frequently applied):
  • II.A.8.1 Material and energy balance: $\sum \dot{m}_{\text{in}} = \sum \dot{m}_{\text{out}}$; $Q = \dot{m} C_p \Delta T$; LMTD: $\Delta T_{lm} = \dfrac{\Delta T_1 - \Delta T_2}{\ln(\Delta T_1/\Delta T_2)}$.
  • II.A.8.2 Gas compression power (polytropic/adiabatic approximation): $\dot{W} = \dfrac{\dot{m}k}{k-1} R T_1 \left[\left(\dfrac{P_2}{P_1}\right)^{\frac{k-1}{k}} - 1\right]/\eta$.
  • II.A.8.3 Pipe pressure drop (single-phase): $\Delta P = f \dfrac{L}{D} \dfrac{\rho v^2}{2} + \sum K \dfrac{\rho v^2}{2}$; multiphase: Beggs–Brill/Lockhart–Martinelli (software-assisted).
  • II.A.8.4 Control valve sizing (liquid): $C_v = \dfrac{Q}{N_1 \sqrt{\Delta P/\rho}}$; choked/FL effects per ISA/IEC.
  • II.A.8.5 Souders–Brown for separator gas capacity: $V = K_s \sqrt{\dfrac{\rho_L - \rho_V}{\rho_V}}$; residence time: $t = V/\dot{V}$.
  • II.A.8.6 Relief rate examples: fire case for vessels per API 521; adiabatic flashing; two-phase de-pressuring time constants.
  • II.A.8.7 Pump head and affinity laws: $H \propto N^2D^2$, $Q \propto ND^3$, $P \propto N^3D^5$ (for similarity scaling).
  • II.A.8.8 Flare radiation: point-source/line-source models; allowable radiant heat at receptors per company/standard limits.
• II.A.9 Data analytics: historian queries, mass balance reconciliation, alarm/event analysis, root-cause methods (5-Why, FMEA).

II.B Soft skills

• II.B.1 Safety leadership and operational discipline; strong MOC and procedure ownership.
• II.B.2 Cross-discipline coordination (operations, mechanical, I&C, electrical, subsurface, projects, vendors, regulators).
• II.B.3 Clear technical writing and drawing markup; decisive field troubleshooting under time pressure.
• II.B.4 Stakeholder alignment, risk-based decision-making, and lifecycle cost thinking.

II.C Physical demands

• II.C.1 Field walkdowns on live facilities; climbing stairs/ladders; extended standing; use of full PPE in hot/cold climates.
• II.C.2 Offshore/sour-service readiness: H2S awareness, BOSIET/medical clearance (where applicable).
• II.C.3 Occasional work at height and in noisy areas during commissioning and testing.

III. Typical tools, software, and equipment

• III.1 Process simulation: Aspen HYSYS/UniSim (steady-state/dynamics), Aspen Plus (as needed), ProMax (treating), OLGA/PIPESIM (network/flow assurance).
• III.2 Relief and flare: Aspen Flare System Analyzer, Flaresim/FlareNet, in-house de-pressuring tools.
• III.3 Heat transfer/thermal: HTRI/Aspen EDR; exchanger rating/selection and fouling analysis.
• III.4 Hydraulic networks: PIPENET, AFT Arrow/Fathom, PIPE-FLO for utility and flare hydraulics.
• III.5 Controls/operations: DCS/SCADA trending, APC tools, data historians (e.g., PI System), alarm management suites.
• III.6 CAD and data: Smart P&ID/AVEVA P&ID, AutoCAD, 3D model viewers, engineering document management systems.
• III.7 Field instruments: flow meters (orifice, Coriolis, ultrasonic), level/interface devices, analyzers (H2S, CO2, moisture), vibration monitors.
• III.8 Testing and inspection: portable gas detectors, pressure gauges, NDT coordination (UT, RT) for integrity follow-up.

IV. Work environment

• IV.1 Location: primarily onshore office or central operations support; frequent site visits to CPF/CPP, terminal, FPSO, or offshore platforms.
• IV.2 Schedule: standard 5–2 office; during commissioning/startup, extended shifts (10–12 hours). Offshore assignments often 14–14 or 28–28 rotations.
• IV.3 Travel: domestic/international 10–40% depending on project phase and asset support model.
• IV.4 Conditions: exposure to hydrocarbon, sour service, and high-noise areas; strict permit-to-work and SIMOPS controls.

V. Reporting lines and cross-functional interfaces

• V.1 Reporting lines
  • V.1.1 Reports to: Process Engineering Lead or Facilities Engineering Manager (project) or Asset Engineering Lead (operations).
  • V.1.2 May mentor junior process engineers and designers; may act as package focal point for specific systems.
• V.2 Key interfaces
  • V.2.1 Operations/Production, Maintenance/Reliability, I&C, Mechanical/Rotating, Electrical, Piping/Pipelines, Metrology/Metering.
  • V.2.2 Subsurface/Production Engineering and Flow Assurance, Planning/Supply Chain, HSE, Quality, Regulatory.
  • V.2.3 EPC contractors, equipment vendors, third-party certifiers/verification bodies, laboratory/PVT providers.

VI. Career ladder and progression

• VI.1 Entry/Intermediate: Process Engineer (this role) — owns systems within a facility; delivers calculations and documents under supervision of a lead.
• VI.2 Next steps
  • VI.2.1 Senior Process Engineer — system owner across trains; HAZOP/LOPA action closure lead; vendor/EPC technical authority.
  • VI.2.2 Lead Process Engineer — project/process lead; design basis owner; multi-discipline coordination; approves key deliverables.
  • VI.2.3 Process Engineering Manager/Technical Authority — governance, standards, competency, and portfolio optimization leadership.
  • VI.2.4 Specialist tracks — Flow Assurance Specialist, Relief/Flare Specialist, Dynamic Simulation Expert, Operations Excellence/Advanced Control.
• VI.3 Progression triggers
  • VI.3.1 Typically promoted after 2–4 projects through detailed design and 1–2 successful start-ups, plus demonstrated plant troubleshooting.
  • VI.3.2 Certifications: Functional Safety (IEC 61511) engineer credential, HAZOP facilitator, offshore survival (if offshore-facing); professional licensure (PE/CEng) accelerates progression.
  • VI.3.3 For lead roles: delivery of a 50,000–200,000 bbl/d or 100–500 MMscf/d facility/train, proven vendor/EPC oversight, and relief/flare dossier ownership.

Deliverables & interfaces

• Deliverables
  • D.1 Basis of Design, PFDs, P&IDs, H&MB, equipment and instrument datasheets, line list, tie-in list.
  • D.2 Hydraulic reports (process/pipeline/flare), PSV sizing and overpressure protection reports, blowdown/de-pressuring studies.
  • D.3 Control narratives, shutdown keys, cause & effect matrices, alarm rationalization, operating procedures/manuals.
  • D.4 Start-up/commissioning plans, performance test procedures, operating envelopes, flare/emissions summaries.
  • D.5 MOC packages, deviation/concession requests, technical queries responses, as-built redlines.
• Interfaces & handoffs
  • I/H.1 Reports to Process Lead/Facilities Manager; hands off approved datasheets and narratives to procurement, I&C, and operations.
  • I/H.2 Provides inputs to mechanical (rotating/static), piping, electrical load lists, and layout teams; receives vendor GAs/calcs for review.
  • I/H.3 Coordinates with operations for procedures/training; with HSE for risk assessments; with regulators on design compliance.

Toolchain snapshot

• Simulation: Aspen HYSYS/UniSim (steady-state/dynamics), OLGA/PIPESIM, ProMax.
• Relief/Flare: Aspen Flare System Analyzer, Flaresim/FlareNet.
• Thermal: HTRI/Aspen EDR.
• Hydraulics: PIPENET, AFT Arrow/Fathom.
• Controls/Operations: DCS/SCADA trending, APC tools, PI System historian.
• CAD/Data: Smart P&ID/AVEVA P&ID, AutoCAD, EDMS.
• Field: Flow/level/pressure analyzers, portable gas detection.

Key highlights

• Safety-critical role ensuring overpressure protection, effective safeguarding, and operability.
• End-to-end ownership from concept and design through commissioning and ongoing optimization.
• Standards-driven work with rigorous documentation and verification for auditability and compliance.