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Slug Catcher Versus Separation Drum

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#1 maryam74


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Posted 20 December 2006 - 07:13 AM

Dear All,

There are two separate 26" gas pipelines in our project which transfer gas to compressor station.
In order to separate the condensate from gas, two different systems are considered for each line. For one pipeline with158 MMSCFD gas flow, a finger type slug catcher and for the other one with 165 MMSCFD a separation drum is considered.
It shall be noted that amount of condensate in the second pipeline is more than the first one.
Now, I want to know that why the designer has used a finger type slug catcher for the first line and a separation drum for the second line and also the fields of applications for each one.

Thanks in advance


#2 Profe


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Posted 21 December 2006 - 03:43 PM

Hi Maryam

Here some hints about your question:

Slugging refers to varying or irregular flows and surges of gas and liquid through any cross-section of a pipeline. The commonest way of handling heavy slugs is to install slug-catchers at onshore receiving plants, which are designed to receive considerable quantities of liquid over short periods.
The slug-stabilizing system is capable of providing slug-handling capabilities at a greatly reduced cost compared to equivalently sized pressure vessels.
Production fluids from the feed gas pipelines will be fed into a slugcatcher(s) to separate the natural gas from the liquids. The slugcatcher(s) will be either a ‘fingertype’ or a ‘vessel-type’. The advantage of the vesseltype is a significant reduction in required land area compared with the more traditional finger-type slugcatcher, which is based on long runs of straight pipes. However, the size of the liquid slugs expected may require use of the finger-type slugcatcher.
The decision on slugcatcher type will be made during subsequent design phases. Current land use estimates assume the greater of the two.

I think that will be useful.

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