BigInch,
Thanks for advice, but I usually read the text first. That is true not from the page 1 until the end but sometimes I skip not relevant sections.
The point is I treated the text literally and could find any example of overpressure protection case due to back-flow. "Gas source"...
The launchers are pipeline piping.
BigInch thanks for your comments and advices, but the discussion is a bit offtopic. I could not find any code requirements for the situation that lower design pressure station is tied-up to the pipeline with higher design pressure. If the pressure spec break...
BigInch, the plant is the brownfield and the scrapers are located inside the plant fence, not outside as it should be done.
The pig launcher is located 8 meters away from the existing metering skid.
BigInch
What about the following scenario:
The plant is functioning with full discharge pressure into the pipelines and ESDV located at the pipeline feeder closes. ESDV closed due to a general shutdown because someone saw a fire and pushed the shutdown button. The fire is in the vicinity of the...
BigInch, now I see your point.
Apology that I have not put the whole story on the table which makes difficult to discuss.
There is an ESD level one which in case of fire blowdowns the plant piping (upstream the ESDV-1). So the fire can be fed with the gas only if the ESDV-1 leaks no matter if...
BigInch thanks for replay.
The only source the plant may experience high pressure from is the pipeline.The plant design pressure is 80 barg, the pipeline A design pressure is 100 barg. Certainly there is no chance to "boost" the pipeline A above 80 barg, but the HH pressure may come from the...
Dear All,
The gas plant is tied-in to the pipeline A. The gas plant design pressure is P1, and the pipeline A DP is P2. The pipeline after few kilometres will end with the metering station and will be tied to the another pipeline (B) than design pressure is P3 see attached sketch)
The Client...
Dear All,
One of our customers is testing the gas well at this moment. During the test they faced enormous scaling production in flowlines and separator.
I have the production water analysis in my hand. The sample was taken from the separator.
Among others the water from the separator has...
Dear Folks,
Does anybody know is it possible to insulate the 4" UG gas flowline.
Due to hydrates formation temp=12 deg C the gas will be heated up with indirect heater upstream the choke. I would like to maintain 12 deg C in the flowline to prevent hydrate formation for the next 4 km. Without...
Dear all,
I am currently working on a plant design for gas well processing plant. It consist of amine washer, 4 stage reciprocating compressor, gas dryer etc. The weather conditions: winter min -25deg C, summer max +30 deg C.
For all of above air cooled coolers are recommended (I saw once S&T...
Maddocks, this is what I have already found. It is really hard to convince them. Not only in this matter (they may be right) but sometimes they are really stuck to only one solution (theirs solution). The thing is, in the BOD, the cold stack vapors disposal solution was approved. Now at the end...
Dear all,
There is a pig receiver at a natural gas plant. Condensate from a pipeline is taken to the vessel through the condesate line with PRV installed. The flashing condensate will get into the vessel causing some HC getting out of the vessel through the breathing valve to the atmosphere...
Thanks Folks.
What I did, I solve this backwards starting from vent stack as suggested by Homayun and API 521 using formulas from API 521 for tailpipe pressure drop. But using this method I was only able to calculate the pressure at the globe valve outlet during the HP depressurization . I...
Dear All,
I am trying to calculate a pressure at a specified point of the vent system header (see point P1 on the attached draft). The purpose of that is to be sure that during the depressurization of HP section of the pipeline connected to the same header as RD, the disk wont rupture. The set...
