Several subsea tie-backs to the shore of gas-condensate fields operate today (Ormen Lange, Snohvit), but they are associated to large reserves and suffer from several weaknesses: the sensitivity to liquid accumulation in the lines, which can lead to an early shutdown of production, in particular in case of water breakthrough; and, the disadvantage of continuous injection of hydrate inhibitors, generally MEG, supplied from shore by a dedicated line. Saipem has recently performed several studies to evaluate the technical feasibility of cases with moderate to large reserves (1-10 Tcf), longer step-outs, and deeper waters, while optimising the recovery factor. There have been investigations of new subsea configurations combined with new operating philosophies, such as: conventional dual production lines, single lines, and subsea gas/liquid separation, possibly combined with subsea wet or dry gas compression. The work performed clearly shows, in some cases, the potential benefit of the subsea gas/liquid separation in reducing the liquid accumulation, leading to an increase of the recovery factor. This extended abstract presents the various solutions with their advantages, limitations, and drawbacks. The first part is dedicated to production considerations, such as the management of the liquid hold-up for low flowrates (end-of-life), turndown conditions, pigging, restart, and impact on the receiving terminal (slug catcher). The interest of using low-dosage hydrate inhibitors is also discussed. The second part focuses on pipeline design from the deepwater field to the shore, as well as on the installation constraints corresponding to the capabilities of the present installation vessels.