Construct hydrate, wax and asphaltene phase behaviour models to define the safe operating envelope of a subsea tieback.
Oil, Gas & Energy
Flow Assurance Management of Hydrates, Wax and Asphaltenes in Subsea Tiebacks
Equips subsea and process engineers to predict hydrate, wax and asphaltene blockage risk in tiebacks and to design the thermal, chemical and operational controls that keep flowlines running.
🗓️Duration5 training days
📚Content4 modules · 8 sessions
🎓On completionAccredited attendance certificate
About the programme
Course Overview
Long subsea tiebacks move unprocessed well fluids across cold seabeds for many kilometres before they reach a host platform or floating facility, and that journey is where hydrates, wax and asphaltenes threaten to block the line. A shut-in that runs a few hours longer than planned, or a cool-down that was underestimated at the design stage, can turn a routine stoppage into a multi-week remediation. This course works through the thermodynamics that govern each blockage mechanism, then moves into the thermal insulation, active heating and chemical inhibition choices used to keep flowing fluids clear of the hydrate envelope and below critical wax and asphaltene deposition rates. Participants build transient multiphase models to test startup, shutdown and restart scenarios, and work through pigging, monitoring and remediation planning used once a tieback is in operation. The course closes with the governance side of flow assurance: the philosophy document, the risk register and the way assumptions are revisited as a field's water cut and pressure change over its producing life. Worked examples are drawn from realistic tieback configurations rather than any single named development.
Expected Learning Outcomes
Design thermal insulation, active heating and chemical injection systems that keep flowing and shut-in fluids clear of blockage risk.
Build transient multiphase simulations of startup, shutdown and cold restart to set safe operating limits and shut-in times.
Specify inhibitor selection, dosage and pigging programmes matched to a tieback's subcooling margin and deposition rate.
Plan pigging, monitoring and remediation operations that detect and resolve emerging blockage risk before it stops production.
Compile a flow assurance philosophy document that sets design margins and integrates with subsea architecture decisions.
Evaluate late-life flow assurance risk as water cut and pressure change, and update inhibition and monitoring strategy accordingly.
Who Should Attend
Subsea and flow assurance engineers designing or supporting deepwater tieback developments.
Process engineers responsible for topside chemical injection and MEG regeneration systems.
Production and operations engineers managing startup, shutdown and pigging on subsea tiebacks.
Field development engineers integrating flow assurance constraints into subsea architecture decisions.
Reservoir and production technologists tracking how changing water cut affects blockage risk over field life.
Flow assurance and simulation specialists building or reviewing transient multiphase models.
Course Modules
Select any module to see its sessions and points.
01Phase Behaviour and Blockage Mechanisms in Multiphase Flowlines
2 sessions · 8 points
Session 1Hydrate Formation Thermodynamics and Risk Mapping
- Construct hydrate stability curves from pressure-temperature data and compositional analysis to define the hydrate formation envelope for a given tieback fluid.
- Apply structure I and structure II hydrate equilibrium concepts to identify which guest molecules control formation risk in a specific gas-condensate stream.
- Use commercial thermodynamic packages such as Multiflash or PVTsim to calculate subcooling margins along the flowline profile under varying seabed temperatures.
- Interpret combined pressure-temperature-time trajectories during shut-in to determine how quickly a flowline crosses into the hydrate-forming region.
Session 2Wax Deposition and Asphaltene Precipitation Mechanisms
- Determine wax appearance temperature and pour point from differential scanning calorimetry and cross-polarised microscopy results.
- Model wax deposition rate along a cooling flowline using molecular diffusion and shear dispersion terms to predict deposit thickness over an operating campaign.
- Assess asphaltene stability using the colloidal instability index and de Boer plot to flag precipitation risk during pressure depletion.
- Distinguish organic deposition from inorganic scale by reviewing solids sampling and pigging return analysis from comparable subsea developments.
02Thermal Insulation, Active Heating and Chemical Inhibition Design
2 sessions · 8 points
Session 1Passive and Active Thermal Management of Tiebacks
- Specify pipe-in-pipe or wet insulation coating U-values against a target cool-down time so the flowline stays outside the hydrate envelope during a defined shut-in period.
- Compare direct electrical heating and hot fluid circulation systems against insulation-only designs for long-offset tiebacks with intermittent production.
- Size subsea heating cables and power supply requirements against a transient cool-down and reheat schedule for a multi-well drill centre.
- Evaluate burial and rock-dumping options as supplementary thermal protection where insulation coating alone cannot meet the required no-touch time.
Session 2Chemical Inhibition and Injection System Design
- Select between thermodynamic inhibitors such as methanol and mono-ethylene glycol and low-dosage hydrate inhibitors based on dosage rate, regeneration needs and topside footprint.
- Size continuous and batch chemical injection systems, including kinetic hydrate inhibitors and anti-agglomerants, against worst-case water cut and subcooling scenarios.
- Specify wax inhibitor and pour point depressant treatment programmes alongside a pigging frequency that keeps deposit thickness within the design allowance.
- Design an asphaltene inhibitor or dispersant squeeze programme and define the sampling regime used to confirm continued effectiveness downhole.
03Transient Multiphase Simulation and Flow Assurance Operations
2 sessions · 8 points
Session 1Transient Simulation of Startup, Shutdown and Shut-in
- Build a transient multiphase model in OLGA or LedaFlow to represent slug flow, liquid holdup and terrain-induced slugging along the tieback profile.
- Simulate cold restart of a waxy crude system, accounting for gelation and yield stress, to define the maximum allowable shut-in time before restart pressure exceeds pump or riser limits.
- Model blowdown and depressurisation sequences to keep the flowline pressure-temperature trajectory clear of the hydrate curve during an unplanned shutdown.
- Validate simulation outputs against field surveillance data such as topside pressure, temperature and multiphase flow meter readings to refine model assumptions.
Session 2Pigging, Monitoring and Field Operations
- Plan a pigging campaign that balances wax and hydrate risk against pig trap capacity, pipeline rating and slug-catcher sizing at the receiving facility.
- Interpret pig receipt data, including wax volume and pressure differential, to adjust inhibitor dosage or pigging frequency for the next campaign.
- Apply digital flow assurance surveillance, including virtual flow metering and machine-learning-based deposition alarms, to detect early blockage risk.
- Draft shut-in and restart procedures that specify inhibitor displacement, depressurisation limits and hold times for operations personnel to follow.
04Flow Assurance Governance across the Field Life Cycle
2 sessions · 8 points
Session 1Flow Assurance Philosophy and Design Integration
- Compile a flow assurance philosophy document that sets subcooling margins, no-touch time targets and inhibitor availability requirements for the design team.
- Integrate flow assurance constraints with subsea architecture decisions, including manifold location, tie-in spacing and umbilical routing.
- Coordinate flow assurance requirements with process design of the host facility, including MEG regeneration and reclamation unit sizing.
- Reconcile conflicting requirements between flow assurance, subsea controls and drilling schedules through a documented risk register and decision log.
Session 2Lifecycle Risk Management and Continuous Improvement
- Update the flow assurance model against actual field data as water cut and gas-oil ratio evolve over the production life of the tieback.
- Assess late-life flow assurance risk, including declining reservoir pressure and increasing water cut, against the original design envelope.
- Plan remediation options for a confirmed blockage, including chemical dissolution, coiled tubing intervention and thermal remediation.
- Capture lessons learned from flow assurance incidents into the philosophy document and inhibitor selection criteria for future tiebacks.
What the participant receives
4 course modules
A structured syllabus
8 training sessions
across 5 days
32 detailed points
Applied, detailed content
Accredited attendance certificate
On completing the programme
Complete your registration
We will contact you within one business day to confirm.
Ready to start?
Reserve your seat and start building the skill.