Experimental Investigation of Particle Deposition and Pipeline Plugging Mechanisms in Produced Fluids from High-Salinity Gas Reservoirs
Bo Zhang1,2,3,4, Guosheng Ai1,2,3,4, Junlin Wu4, Mingyi Zhang1,2,3,4, Xinqing Zhang5,*, Cong Li1,2,3,4, Xuanwei Zhang1,2,3,4, Na Li1,2,3,4, Limin Yuan1,2,3,4
1 R&D Center for Ultra-Deep Complex Reservior Exploration and Development, CNPC, Korla, China
2 Engineering Research Center for Ultra-Deep Complex Reservoir Exploration and Development, Xinjiang Uygur Autonomous Region, Korla, China
3 Xinjiang Key Laboratory of Ultra-Deep Oil and Gas, Korla, China
4 Tarim Oilfield Company, PetroChina, Korla, China
5 College of Petroleum Engineering, Xi’an Shiyou University, Xi’an, China
* Corresponding Author: Xinqing Zhang. Email: 
Fluid Dynamics & Materials Processing https://doi.org/10.32604/fdmp.2026.086215
Received 26 May 2026; Accepted 31 July 2026; Published online 13 August 2026
Abstract
This study investigates the physicochemical characteristics, particle deposition behavior, and plugging mechanisms of produced fluids from drainage-gas recovery wells in high-salinity gas reservoirs, using a representative well from the Tarim Oilfield as a case study for a broad class of production systems affected by liquid-phase pipeline plugging. A comprehensive experimental methodology was adopted, combining physicochemical characterization, filtration and static sedimentation experiments, dynamic deposition tests, scanning electron microscopy coupled with energy-dispersive X-ray spectroscopy (SEM-EDS), and X-ray diffraction (XRD). This combined experimental approach was employed to identify the dominant deposition mechanisms and determine the particle-size fractions most responsible for pipeline plugging. The produced fluid was identified as a high-salinity, weakly acidic CaCl
2-type aqueous system with potential scaling tendencies associated with BaSO
4, SrSO
4, and CaCO
3. Particle-size analysis revealed that particles were predominantly distributed within the 2–10 μm range, representing 58.89% of the total particle population and constituting the principal plugging-risk fraction. In particular, particles between 2 and 5 μm were found to play a dominant role in turbidity breakthrough, membrane bridging, and the initiation of deposit formation. Microscopic characterization further showed that the deposits consisted primarily of NaCl, CaCO
3, SiO
2, together with minor sulfate- and metal-containing phases, indicating a composite deposition mechanism involving both suspended particles and salt crystallization.
Keywords
High-salinity produced fluid; pipeline plugging; particle-size distribution; dynamic deposition; composite deposition mechanism
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