Production engineering is where reserves turn into cash flow. The reservoir engineer estimates what is in the ground and how it will be drained; the production engineer decides how each well is completed, how it flows, how it is lifted and how it is kept producing. Decisions made here, such as tubing size, completion type, perforation strategy and lift method, fix a large share of a well's lifetime production and operating cost, and many of them are expensive to change once the well is on stream.

A well's rate is not set by the reservoir alone. It is the result of the whole production system: reservoir inflow, near-wellbore damage, completion restrictions, tubing flow, the choke, the flowline and separator pressure. Each part takes a share of the available pressure. A change in one part, such as falling reservoir pressure, rising water cut or higher separator pressure, changes the rate the whole system can deliver. This is why production engineers work with inflow performance and vertical lift performance together rather than looking at any component in isolation.

Wells also change over their life. Reservoir pressure declines, gas comes out of solution, water breaks through and solids start to deposit. A well that flowed naturally at start-up may need artificial lift within a few years, and a gas well that produced cleanly may start loading up with liquid. Production engineers have to anticipate these changes at the design stage and recognise them early in surveillance data.

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

• Describe the components of the production system and how they interact from the reservoir to the separator.
• Apply reservoir fluid properties (PVT) to production engineering calculations.
• Construct inflow performance relationships for oil and gas wells.
• Quantify skin and identify the main formation damage mechanisms.
• Explain the main completion types and the function of key completion components.
• Calculate pressure losses in tubing, flowlines and chokes for single-phase and multiphase flow.
• Perform nodal analysis to predict well rates and diagnose underperforming wells.
• Compare artificial lift methods and select a suitable method for given well conditions.
• Identify stimulation candidates and common production problems, and outline their remedies.

Organisations sending participants to this training will:

• Have engineers who understand the full production system and can identify where a well is losing rate.
• Improve well design decisions on tubing size, completion type and perforation strategy.
• Make better-informed artificial lift selection decisions based on well conditions.
• Reduce unnecessary stimulation and workover spend through better diagnosis of well problems.
• Identify production problems such as sand, scale, wax and liquid loading earlier.
• Improve communication between reservoir, drilling, completions and facilities teams.

Participants will:

• Understand how inflow, completion, tubing and surface constraints combine to set well rate.
• Be able to build and interpret IPR and nodal analysis plots.
• Understand skin and be able to judge whether a well is a stimulation candidate.
• Know the operating principles, strengths and limits of the main artificial lift methods.
• Recognise common production problems in well data and know the standard remedies.
• Build a solid base for more advanced production and artificial lift courses.

• Production engineers in their early career
• Petroleum engineers moving into production roles
• Reservoir engineers who want a working knowledge of the production side
• Drilling and completion engineers
• Operations and facilities engineers
• Production technologists and field supervisors
• Graduate engineers entering the oil and gas industry

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.