This paper presents a flow assurance analysis evaluating the efficacy of Dry Gas Displacement (DGD) as a hydrate management strategy for a subsea tieback development. DGD utilizes dry gas imported from the host facility’s gas export line, which is circulated through a dual flowline configuration. The injected dry gas displaces pipeline liquids, mitigating hydrate formation during shutdown and restart. The displaced liquids are then transported back to the topside facilities for subsequent storage or routing to the oil export line. Transient multiphase flow simulations were performed to assess key operational parameters, including required dry gas injection rates, liquid displacement volumes, and the potential for subcooling during restart operations. The analysis considered various production scenarios, including variations in flow rate, water cut, and ambient temperature. Results demonstrate the technical feasibility of DGD for preventing hydrate formation, quantifying the required gas volumes and assessing the impact on downstream processing facilities. The study highlights the influence of key parameters on the DGD process and provides insights for optimizing its implementation within the dual flowline architecture. This paper concludes that DGD offers a robust and technically viable alternative to conventional hydrate management methods for subsea tiebacks, leveraging existing infrastructure for efficient and cost-effective operation.