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Abstract The primary objective of this paper is to share field experience on managing multiphase pipelines with high liquid holdup. Due to operational constraints, there was an urgency to variate the exporting gas flow rate from offshore platform to the receiving terminal, leading to dynamic flow conditions and high liquid holdup in one of the trunkline pipelines. The situation required urgent decision-making to re-strategize the monthly operational pigging activity, which needed to be performed according to the corrosion management plan and flow assurance requirements. A thorough and immediate assessment was required to avoid process interruption at the receiving terminal due to the slugging effect during pig arrival. The focus is on how to perform pigging operations at high liquid holdup without causing process interruption at the receiving terminal. The scope includes evaluating the optimum conditions to perform operational pigging by assessing the liquid holdup behaviour, the pig travelling speed, the pigging duration estimation and the liquid processing time using real-time data. To achieve the objective, the study utilizes a multiphase flow simulation application capable of leveraging real-time data to accurately evaluate the liquid holdup, the liquid processing time, and the pigging duration based on various gas flow rates. This ensures the simulations performed accurately reflect the actual pipeline operating conditions. This approach minimizes model tuning and expedites the assessment process through the identification of optimal pigging strategies and the development of scenarios that can effectively control liquid arrival at the receiving terminal, thereby preventing process upsets and enhancing overall pipeline performance during operational pigging. Four assessment scenarios were established aimed at controlling the liquid arrival at the receiving terminal to avoid process upsets including adjusting the gas flow rate prior and during operational pigging. The established scenarios simulate the behaviour of liquid holdup inside the pipeline, the pig travelling speed during operational pigging, the estimated pigging duration and the liquid processing time at the receiving terminal under different pigging scenarios, allowing for more informed decision-making and improved operational efficiency. Scenario 3 is selected as the recommended operational pigging condition since the liquid arrival is controlled, minimizing the sudden slug arrival as the pig arrives at the receiving terminal and reducing the impact of process upset due to high liquid levels in the slugcatcher. The study concludes that real-time data integration is crucial in predicting and managing liquid dynamics in gas-condensate pipelines, ultimately contributing to more efficient pigging operations.