Hydrates are the fastest acting flow assurance threat and the most immediately dangerous. They form when water and light hydrocarbons meet at sufficient pressure and low temperature, conditions that are routine in gathering systems and unavoidable during an unplanned shutdown when a line cools to ambient. A hydrate plug can form within hours, is capable of accelerating along a line at high velocity when pressure is released incorrectly, and has caused fatalities and equipment destruction. Hydrate management is therefore built into facility design, inhibitor systems, insulation and operating procedure rather than treated as a chemical issue.

Wax and asphaltene deposition act more slowly but are equally capable of stopping production. Wax deposits when the pipe wall falls below the wax appearance temperature, and the deposit thickens and hardens over time until pigging can no longer remove it. Asphaltenes precipitate when pressure falls through the onset envelope, which often occurs in the tubing rather than the flowline, and deposits accumulate in the completion and choke where they are difficult to reach. Both threats depend on the specific crude, which is why fluid characterisation with laboratory measurement of wax appearance temperature and asphaltene onset conditions is a prerequisite for a credible strategy.

Scale and corrosion are water-driven and become more significant as water cut rises. Scale precipitates when water becomes supersaturated through pressure drop, temperature change or mixing of incompatible waters, and carbonate scale in particular can plug tubing rapidly. Corrosion in the presence of carbon dioxide, hydrogen sulphide, oxygen or bacteria consumes containment and is managed through material selection, inhibition, monitoring and operating practice.

Finally, all of these interact. Emulsions raise viscosity and change pressure drop. Sand provides nucleation sites and damages inhibitor films. Chemical treatments intended for one threat can worsen another. A flow assurance strategy that treats each threat separately usually costs more and works less well than one built on an understanding of the whole system.

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

• Characterise produced fluids to identify which flow assurance threats apply to a given system
• Predict hydrate formation conditions and design thermodynamic and kinetic inhibition strategies
• Evaluate wax deposition risk using wax appearance temperature and thermal profile and select prevention methods
• Assess asphaltene precipitation risk and specify dispersant and operational control measures
• Predict scale formation and design inhibition programmes including continuous injection and squeeze treatment
• Analyse corrosion mechanisms in production systems and specify inhibition, monitoring and material responses
• Evaluate multiphase flow and slugging behaviour and specify slug mitigation measures
• Design thermal management using insulation, burial, heating and flow rate control to maintain fluids outside deposition envelopes
• Develop operating procedures for start-up, shutdown, depressurisation and remediation that manage flow assurance risk

The training begins with fluid characterisation and thermal and hydraulic behaviour, then addresses each flow assurance threat with its formation mechanism, prediction method, prevention options and remediation route, so that the strategy for a system is assembled rather than applied by convention. Hydrate curves, wax appearance data, asphaltene envelopes, scaling indices and corrosion rate estimates are worked through numerically. Field cases of blocked lines, plugged tubing, failed inhibition programmes and hydrate incidents are examined in detail, including the operating decisions that produced them. Participants are encouraged to bring flow assurance problems from their own systems for group assessment.

Organisations sending participants to this training will:

• Reduce production deferment caused by blocked flowlines, plugged tubing and restricted chokes
• Reduce the safety exposure associated with hydrate plug formation and incorrect depressurisation
• Optimise chemical expenditure by matching inhibitor selection and dosage to the actual threat
• Extend the life of flowlines and completions through better corrosion and scale management
• Improve the quality of operating procedures for shutdown, restart and extended cold periods
• Strengthen technical review of flow assurance studies and contractor recommendations

Participants will:

• Identify which flow assurance threats apply to a given system and why
• Predict hydrate, wax, asphaltene and scale conditions from fluid and operating data
• Design integrated prevention strategies rather than treating threats individually
• Write and assess operating procedures that manage flow assurance risk during transients
• Diagnose a restricted or blocked line and select the correct remediation method
• Build specialist capability that spans production, facilities and chemistry

• Production, facilities and process engineers
• Flow assurance and subsea engineers
• Production chemists and chemical treatment specialists
• Operations engineers and supervisors managing flowlines and gathering systems
• Pipeline and integrity engineers
• Well intervention and completion engineers dealing with deposition problems
• Design engineers working on gathering system and facility thermal design

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.