SPE-207126-MS A Review of Wet Gas Flow Metering Correlation Solomon Adenubi, Dulu Appah, Emeka Okafor, Victor Aimikhe, and Wilfred Okologume, Petroleum Engineering Department, University of Port Harcourt, Nigeria Copyright 2021, Society of Petroleum Engineers This paper was prepared for presentation at the Nigeria Annual International Conference and Exhibition held in Lagos, Nigeria, 2 - 4 August 2021. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract Entrained liquids in produced natural gas introduce flow-prediction errors in gas metering; hence there is a need to correct flowmeters’ response to these errors. The development of improved wet gas flow correlations is an effective means of optimizing the predictive capabilities of these meters. This study reviews selected wet gas flow correlations, assesses their merits and demerits, and offers novel options and possibilities for developing highly optimized wet gas correlations for industrial applications. Prospects and possibilities for developing highly optimized wet gas flow correlations are also suggested in this paper, resulting in a significant expansion of the use of wet gas flow meters. These possibilities will include model development and experimental investigation of wet gas flows under relatively high-pressure operating conditions. INTRODUCTION Natural gas production often includes liquid fraction in a wet gas flow which consists of water, hydrocarbons, and condensates (Zhang and Liu, 2019). Wet gas is essentially a flowing mixture of gas and liquid, with the fluid making up a small fraction of the mix at less than 5-10% and Lockhart- Martinelli parameters less than 0.3 (Steven, 2002). These small quantities of entrained liquids introduce flow-prediction errors into gas measurements (Tomaszewska-Wach and Rzasa, 2020 & Bai and Zheng, 2017). Differential Pressure (DP) meters comprising Venturi tube meters, V-Cone meters, and Orifice plate meters (Zheng et al., 2017) are the most widely used single-phase meter for wet gas measurement. This is due to their low costs, simplicity of construction, and accuracy of measurement (Bai and Zheng, 2017). However, when DP meters measure natural gas with liquid content, it results in Over-reading (OR). The OR investigation is the basis for existing wet gas correlations (Bai and Zheng, 2017). Thus, a "simple" wet gas correction term applied to the indicated gas mass flow rate will estimate the corrected mass flow rate (Collins et al., 2015). In the oil and gas industry, many scenarios portray the existence of wet gas occurrences. In the Niger Delta, like other locations, many operators do not process their gas efficiently but instead only use the Joule- Thompson valves to knock out liquids before transporting it to users for proper conditioning due to financial and other related technical constraints. Some new offshore field developments, due to economic reasons, transport raw natural gas through multiphase flow pipelines to the nearest existing process facilities offshore or onshore. These constitute wet gas that influences liquid-induced prediction errors that require appropriate Downloaded from http://onepetro.org/SPENAIC/proceedings-pdf/21NAIC/3-21NAIC/D031S018R006/2454847/spe-207126-ms.pdf by Solomon Adenubi on 02 August 2021