Select optimum configuration for an offshore MEG recovery unit

A newly discovered field, 50 km offshore, will be developed over the next five years, with production expected to come online in 2019. The production will be brought onshore, where it will be processed and delivered to customers. Given the location of the subsea wells and the production pressure/temperature profile, mono ethylene glycol (MEG) injection will be used to prevent the formation of hydrates. The Process Design Basis shows the information received from the Flow Assurance engineer, Table 1. Rich MEG, delivered to the MEG recovery unit, typically comes from the plant slug catcher and inlet separator. This liquid feed typically contains a high level of dissolved hydrocarbons (0.5–2.0 vol%), including a high concentration of CO2. If left in solution, these hydrocarbons could accumulate in the process, leading to foaming, reduced boiling, or throughput issues with the vacuum compressor. To remove these dissolved hydrocarbons, a rich, MEG flash vessel will be included in the design.

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