Crude oil velocity in pipelines for various API grades
Crude oil velocity in pipelines for various API grades
(OP)
Does anybody know if there are recommended values (list, table etc) for maximum velocities of crude oil in pipelines depending on crude API and type (e.g. waxy, asphaltenic etc) ??
Thanks and regards,
MRS
Thanks and regards,
MRS





RE: Crude oil velocity in pipelines for various API grades
For erosion, I've typically seen the Vmax = 100 / (rho)^0.5 used or the 100 replaced with 150 in some cases. For clean oils, I would be willing to go higher (sand or solid particles is what you are concerned about) if necessary though your pressure drop over a long run will be high.
I've not familar with any more detailed numbers getting into the oil density (other than above) or the type of oil.
RE: Crude oil velocity in pipelines for various API grades
RE: Crude oil velocity in pipelines for various API grades
RE: Crude oil velocity in pipelines for various API grades
TD2K: could you please indicate what is "rho" ??
BigInch: 3-10 is a good approx. taking into considereation the sand-dirt issue (absence of it).
Monaco: also a good ref. (API specific rule), will check it.
The situation actually encompasses a preliminary evaluation / audit of a production facility. So, there is a portion of multiphase flow from fields to flow stations, then separated oil ("clean") from production tankfarms to refining and/or shipping (various pipelines). API is from 7 to 14 (maybe 19) depending on the flow point (well, field-to-flow station or production tanks to shipping or refining). The API difference is due to diluent added all along the production chain.
Thanks and regards,
MS
RE: Crude oil velocity in pipelines for various API grades
RE: Crude oil velocity in pipelines for various API grades
RE: Crude oil velocity in pipelines for various API grades
RE: Crude oil velocity in pipelines for various API grades
IMO, and if you have the NPSHA to spare, there is no need to keep flow velocities before pumps lower than 15 fps. This is proven by the fact that pipe diameter usually change at the pump inlet nozzle, when they actually reduce diameter by one size. That is because you can theoretically get NPSHA credit for the V^2/2/g term, although to be a little conservative, this term is usually ignored in NPSHA calculations. The real reason you generally want to limit velocities over very short runs of small diameter piping in pump stations is to try to ensure you are not losing too much of NPSHA, which is generally in short supply at pump suctions, but if that's no problem, you can raise velocities higher than even 15 ft/sec.