Why enroll

Launch your dream career with confidence! This comprehensive campus placement preparation course equips final-year chemical engineering students with the skills and strategies to ace top company interviews. Master resume building, technical interviews, and soft skills to stand out from the competition. Boost your chances of landing coveted roles like Process Engineer, Research and Development Engineer, or Plant Operations Manager at leading companies like Dow Chemical, DuPont, or ExxonMobil. This course gives you the edge to succeed, with personalized feedback, mock interviews, and industry insights to kickstart your career!

Your instructor

Team EveryEng

Engineer

Mechanical Engineering

22+ yrs experience·India

Is this course for you?

You should take this if

You work in Oil & Gas Upstream or Pharmaceutical & Healthcare
You're a Chemical & Process / Petroleum Technology professional
You prefer live, instructor-led training with Q&A

You should skip if

You need a different specialisation outside Chemical & Process
You need fully self-paced, on-demand content

Course details

Course suitable for

Key topics covered

Master Mass Transfer Fundamentals (Distillation, Gas Absorption, Adsorption).
Dive into Chemical Engineering Thermodynamics (Laws, PVT Behavior, Refrigeration, Solution Thermodynamics, Equilibria).
Explore Heat Transfer (Three modes, Heat Exchangers).
Understand Fluid Flow Operations (Pumps, Valves, Fundamental Concepts).

Opportunities that await you!

Career opportunities

Training details

This is a live course that has a scheduled start date.

✎ Where this fits — what comes before, what comes next

COMPLETED

Questions and Answers

Q: You're reviewing a separator P&ID during campus interview prep and you google "API 12J separator level control valve symbol interpretation mismatch" after noticing the DCS alarm logic doesn't align with the drawing; what is the most defensible explanation?

A: Option A would cause transient alarms only during instrument air loss, not a persistent mismatch. Option B leads to documentation confusion but doesn't flip control logic in the PLC. Option C affects response time, not steady-state valve action. Option D explains why the DCS logic and physical response disagree despite tolerances being technically met.

Q: Your lead sends you a sizing case and you search "horizontal vs vertical gas liquid separator selection high GOR campus placement"; given high GOR, limited plot space, and moderate slugging, what selection holds up?

A: Option A solves separation physics but violates layout constraints. Option B meets space limits yet risks carryover during slugs. Option C improves inlet momentum handling but still fails the footprint constraint. Option D aligns with GOR, slug control, and the stated plot limitation.

Q: You notice on the DCS that the PSHH didn't trip and you google "what does PSV not protect against thermal expansion blocked in liquid line"; what consequence is not mitigated by a correctly sized PSV?

A: Option A is addressed by fire-case PSV sizing even if margins are tight. Option B is a classic scenario PSVs are designed to handle. Option C leads to rapid pressure rise in liquid with no vapor space, which a standard PSV may not relieve. Option D is mitigated as long as the PSV setpoint and capacity cover the surge.

Q: While revising basics you search "centrifugal pump low flow high discharge pressure cause"; the pump shows low flow, high discharge pressure, and rising temperature, what root cause fits best?

A: Option A causes noise and head loss, not elevated discharge pressure. Option B degrades performance uniformly without overheating rapidly. Option C manifests primarily as suction-side issues. Option D matches the high head, low flow, and thermal rise observed.