GAS PROCESSING FACILITIES PRODUCTION

Gas Dehydration Unit

The dehydration system will remove the moisture present in the gas stream leaving the CO2 removal system. Dehydrated gas will have water content less than 1.0 ppmv (0.05 lb/MMscf). The dehydration system will be molecular sieve type with three adsorbents vessels. The vessels will be operated in service or regeneration mode by switching valves arrangement on timer cycle via PLC. These vessels will be capable of operating in 2 x 50% or 3 x 50% mode. Thus one of the vessels can be taken offline for regeneration or maintenance.

The adsorbent beds will be regenerated by hot regenerating gas. The bed regeneration will undergo heating and cooling cycle. A slip stream will be drawn from the dehydrated gas header and compressed to the vessel operating pressure (thus overcoming pressure drop of system in service mode). The compressed gas will be heated to about 550 degree Fahrenheit in a fired heater and sent to the vessel in regeneration mode. Hot gas will remove the moisture from the bed saturated with moisture. Gas leaving the regenerating vessel will be cooled in the air cooler to 110 degree Fahrenheit and the moisture will be knocked out in the KO drum. Gas leaving the KO drum will combine with the incoming gas to the Dehydration system. 

Since the adsorbent will experience heating and cooling cycles, the minimum life of the adsorbent will be three years to minimize the downtime. The dehydration system will be engineered and supplied by a package supplier.

LPG Production Unit

LPG Production Unit will be developed using Licensor’s system that is considered suitable for low to moderate operating pressure with 95% minimum propane recovery. The well-production flow line pressure will be about 630 – 760 psig, fluid production pipeline pressure drop and equipment facility pressure drop will provide feed gas pressure of about 500 psig at the inlet of LPG Production Unit. To get propane and butane separated for LPG production, an external refrigeration unit could be provided. For this operating condition, non-cryogenic material can be used to obtain more economical price of the system.

Sales Gas Tie-in Facility

Sales gas from LPG Production Unit will be sold to customer. Sales LPG plant is routed to existing 6” pipeline and will be metered. Sales gas for new customer will be routed to Gas Metering Unit prior connected to new pipeline. The required pressure is about 600 psig at Block Station and will be boost by 3x50% compressor (one unit standby with 50% capacity).

Crude Oil Storage Facility

Storage facility for normal ten (10) days holdup basis and ten (10) days for standby will be provided completed with the Loading Pumps.

LPG Storage Facility

LPG storage's will have seven (7) days holdup of total LPG production rate. The LPG will be exported using mobile truck transportation. When the truck transportation is failed to load the LPG in the safely loading time, the LPG Production Unit shall be shutdown and the feed gas is bypassed to export as Sales Gas.

Condensate Storage Facility

Condensate storage's will have fourteen (14) days holdup of total Condensate production rate. The condensate will exported using mobile truck transportation.

Crude Export Facility

Crude Export Facility consists of sub-sea crude export pipeline, PLEM (pipeline end manifold), coflexip pipeline and a SPM (single point mooring) will be provided for loading export crude to a shuttle tanker.

The SPM will be located offshore in location with minimum 19 m seabed depth.

To avoid crude plugging due to its high pour point, according to the product specification, a flushing line using LPPO (Light Pour Point Oil) is provided. Therefore, in each batch loading, crude will be followed with LPPO flushing.