The design of wet-gas pipelines and slug catchers requires multiphase flow simulations, both steady-state and transient. However, steady-state simulation is often inadequately conducted and its potential not fully utilized. This paper shows how mechanistic steady-state simulation models can be used to obtain not only pressure drop, liquid holdup and flow regime, but also to extract important operational information such as pig transit time, pig exit speed, liquid buildup rate behind the pig, and the time for the pipeline to return to a steady-state after pigging. A well-designed set of steady-state simulations helps to determine pipeline size, slug catcher size, and pigging frequency. It also serves as a starting point for subsequent transient multiphase flow simulations.

1.
API RP 14E, 1991, Recommended Practice for Design and Installation of Offshore Production Platform Piping Systems, American Petroleum Institute, Fifth Edition, October 1.
2.
Bendiksen, K. H., Malnes, D., Moe, R., and Nuland, S., 1991, “The Dynamic Two-Fluid Model OLGA: Theory and Application,” SPE Production Engineering, May, pp. 171–180.
3.
Danielson, T., and Erickson, D., 1997, “A Comparison of ConOLGA With Field Data From a Gas Condensate Pipeline,” Proceedings, BHR Group Multiphase, Mechanical Engineering Publications Limited, Bury St Edmunds and London, U.K., pp. 19–41.
4.
Engineering Data Book, 1994, Revised 10th Edition, Vol. 2, pp. 20–4, Gas Processors Suppliers Association, Tulsa, OK.
5.
Shea, H. S., Rasmussen, J., Hedne, P., and Malnes, D., 1997, “Holdup Predictions for Wet-Gas Pipelines Compared,” Oil & Gas Journal, May 19, pp. 73–75.
This content is only available via PDF.
You do not currently have access to this content.