Flare design 1

[michael99]

Question on flare Scenarios
Note this for an oil and gas platofrm offshore.
I have been asked to look at the production flaring case on a platform. All the literature for the platform indicates the worst case in this scenario is a tube rupture coincident with production flaring. WE have on my 1st stage separators PCVS for this scenario. When calculating this case do i take the maximum flowrate through the PCV at min back pressure or the production flowrate.

If anyone can point me to a good description of flare cases this would be most helpfull.
Thanks in advance michael

 

[dcasto]

Not quite clear. If you mean production flowrate, do you mean that all the maximum potential production going to the flare? If so, how would you have any more from within the process to go through a PCV?

 

[0707]

In your case you have to do a risk assessment in your platform. After that you will be in position to ranking the worst possible scenarios and act accordingly.

I do not know, maybe the sites bellow gave you some light on the subject

http://www.johnzinc.com/products/flares/pdfs/tp_hostile.pdf

http://www.johnzink.com/products/flares/pdfs/tp_safe.pdf

http://www.touchbriefings.com/pdf/951/argo_2_tech.pdf

Luis marques

 

[michael99]

WE can have a scenario when the tube rupture occurs, in my case this is the aftercooler on the 3rd stage compressor this is a bursting disc case. In coincidence we can also flare the production. Note this is only what i would called a temporary flaring scenario. WE have PCVs on the 1st stage and 2nd stage separators to enable this to happen. the PCV routes the inventory to the HP flare prior to the wells shutting in. Note the wells shut in due to the ESD logic associated with the tube rupture case. What i was trying to find out was do you take the PCV at the normal or HH pressure when calculating the max rate through the PCV. I am trying to find out the sizing case for the through put.
king regards michael