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Flare Package System Design and Application

Team EveryEng

Team EveryEng

Mechanical Engineering

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Flare Package System Design and Application

  • Trainers feedback

    4

    (1419 reviews)

    Team EveryEng

    Team EveryEng

    Mechanical Engineering

  • Course type

    Watch to learn anytime

  • Course duration

    58 Min

  • Course start date & time

    Access anytime

  • Language

    English

Why enroll

Ignite your career in the oil and gas industry with expertise in Flare Package System Design and Application! By mastering this specialized skill, you'll become a sought-after professional in roles like Process Engineer, Facilities Engineer, or Project Manager, with opportunities for career advancement, higher earning potential, and global job prospects. With knowledge of flare system design and application, you'll ensure safety, compliance, and efficiency in oil and gas operations, making you a valuable asset to companies and opening doors to leadership roles and consulting opportunities.

Opportunities that awaits you!

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Course content

The course is readily available, allowing learners to start and complete it at their own pace.

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Flare Package System Design and Application

3 Lectures

58 min

  • Lesson icon

    Environmental Impact

    14 min

  • Lesson icon

    Flare types and its component

    19 min

  • Lesson icon

    Flare System Design

    25 min

Course details

Flare System Design is very critical for Oil and Gas Industry

It is necessary to get rid of excess gas, and occasionally liquids from a facility. The safest way to do that is with the Flare System.

A Flare System is an arrangement of piping and specialised equipment that collects hydrocarbon releases from relief valves, blowdown valves, pressure control valves and manual vents and disposes of them by combustion at a remote and safe location

A gas flare, or flare stack, is a gas combustion device used in industrial plants such as petroleum refineries, chemical plants, natural gas processing plants, and at oil or gas production sites with oil wells, offshore oil and gas rigs/platforms and landfills

Onshore and Offshore Flare Systems Gas flaring systems are installed on onshore production fields, offshore platforms, on transport ships and in port facilities, at storage tank farms and along distribution pipelines. So what are the main differences between an onshore (refinery) Flare System and an offshore (platform) Flare System?

The equipment required for both onshore and offshore Flare Systems is essentially the same. However:

• Noise and radiation is more of a problem for an offshore facility due to the closer proximity of personnel

• More space availability for an onshore facility allows flare tips to be located away from the main process site

• Additional space onshore allows for the installation of spare flares if required and the potential use of Ground Flares

This Course will be very helpful to all Oil & Gas Professional to under Flare Package System

Course suitable for

  • Oil & Gas
  • Pharmaceutical & Healthcare
  • Energy & Utilities
  • Chemical & Process
  • Electrical
  • Mechanical

Key topics covered

1. Introduction in Brief

2. Environmental Impacts

3. Flare System Components

4. Important Definitions

5. Flare Header

6. Flare Knockout Drum

7. Water Seal

8. Flare Stack

9. Flare Stack Components

9. Flare Gas Measurement

10. Flare Recovery

11. Maintenance & Trouble Shooting

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Why people choose EveryEng

Industry-aligned courses, expert training, hands-on learning, recognized certifications, and job opportunities—all in a flexible and supportive environment.

Team EveryEng

Team EveryEng

Mechanical Engineering

Questions and Answers

Q: You're sizing a KO drum for a refinery flare header and end up searching "flare knockout drum sizing vapor velocity API 521 refinery" after a review comment. The drum handles only gas relief from PSVs with no credible liquid carryover, but upstream piping is carbon steel with corrosion allowance already tight. What design choice best aligns with typical API-based practice?

A: A fits the stated duty: gas-only relief with no liquid scenario, so velocity control is the driver. B imports a slugging assumption from multiphase headers and forces unnecessary volume. C ignores liquid from condensation and startup; liquid seals aren't protection upstream. D adds internals that raise ΔP and fouling risk without solving corrosion margin.