Wells are rarely in true steady state. Rates change when chokes are adjusted, wells are shut in and restarted, lift gas supply fluctuates and liquid accumulates and clears in the tubing. Steady-state models average over these changes and can miss the behaviour that causes trips, lost production and flow assurance problems.

Dynamic models capture that behaviour. They show how long a well takes to clean up after start-up, whether it will unload after a shut-in, how large slugs will be and how quickly the tubing cools after a shutdown. These results feed directly into operating procedures, cooldown times, inhibitor injection plans and facility design.

Dynamic models also bring new risks. They need more data, more careful setup and more judgement to interpret. Common mistakes include using poorly defined boundary conditions, choosing time steps and grids that hide the behaviour of interest, and treating simulator output as fact without comparing it with field data. This course gives engineers the foundation to use dynamic models with understanding.

By the end of this training, participants will be able to:

• Explain the difference between steady-state and transient well modelling and when each is needed.
• Describe the conservation equations and closure relationships used in transient multiphase flow simulation.
• Build a basic dynamic well model, including geometry, fluids, boundary conditions and numerical settings.
• Simulate and interpret well start-up and shut-in behaviour.
• Identify and analyse hydrodynamic, terrain-induced and severe slugging.
• Model liquid loading and unloading in gas wells.
• Analyse gas lift instability and heading.
• Evaluate thermal transients and their effect on hydrate and wax risk.
• Validate dynamic model results against field data and use them to support operating procedures.

Organisations sending participants to this training will:

• Have engineers who understand when steady-state models are not enough.
• Improve start-up, shut-in and restart procedures using dynamic model results.
• Reduce production losses and trips caused by slugging and gas lift instability.
• Plan liquid loading remedies and hydrate and wax prevention with better information.
• Improve the quality of dynamic modelling work commissioned from specialists.

Participants will:

• Understand the physics behind transient multiphase flow simulation.
• Be able to build and set up a basic dynamic well model.
• Be able to recognise slugging, loading and instability in model results and field data.
• Understand thermal transients and their link to flow assurance risk.
• Be able to judge the credibility of dynamic model results.

• Production engineers
• Flow assurance engineers
• Well performance and optimisation engineers
• Artificial lift engineers
• Facilities and process engineers working with well inflow
• Subsea and pipeline engineers
• Engineers moving into dynamic modelling roles

Upon successful completion of this training course, delegates will be awarded an official Certificate of Completion issued by the Petroleum Engineers Association (PEA), an ISO 9001:2015 certified training organization. The certificate carries 10 Credits and formally records the total learning hours completed.

Each certificate is signed by the Course Facilitator and the CEO of the Petroleum Engineers Association, and serves as verifiable proof of professional training that delegates can present to employers and professional bodies worldwide.