Quantitative Evaluation of Residual Acid Invasion and Flowback in Fractured-Vuggy Carbonate Reservoirs Using Microfluidics

Jianchao Cai (), Jin Yang, Zhiwen Huang, Sai Xu, Lufeng Zhang and Han Wang
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Jianchao Cai: Key Laboratory of Marine Oil & Gas Reservoirs Production, Sinopec, Beijing 100083, China
Jin Yang: College of Geoscience, China University of Petroleum, Beijing 102249, China
Zhiwen Huang: Petroleum Exploration and Production Research Institute, Sinopec, Beijing 100083, China
Sai Xu: Oil & Gas Technology Research Institute, Changqing Oilfield Company, CNPC, Xi’an 710018, China
Lufeng Zhang: Petroleum Exploration and Production Research Institute, Sinopec, Beijing 100083, China
Han Wang: College of Geoscience, China University of Petroleum, Beijing 102249, China

Energies, 2025, vol. 18, issue 5, 1-16

Abstract: Acid fracturing has become a crucial technology for developing carbonate reservoirs, playing a particularly significant role in enhancing oil and gas recovery. However, the retention and flowback behaviors of residual acid in fractured-vuggy carbonate reservoirs after acid fracturing remain poorly understood, and this uncertainty significantly hinders the efficient development of such reservoirs. In this study, the micro-computed tomography images of carbonate rocks were used to extract actual fracture–vug structures. A microscopic flow model for fractured-vuggy carbonate reservoirs was then designed and fabricated using wet etching techniques. Microfluidic experiments were performed to investigate the invasion and flowback behavior of residual acid within these reservoirs. This study introduces a novel approach by integrating actual fracture-vuggy structures from micro-CT images into a microfluidic model, providing a more realistic representation of fractured-vuggy carbonate reservoirs compared to previous studies that relied on simplified or idealized geometries. Additionally, the invasion coefficient (the ratio of acid invaded area to total pore area) and flowback rate (the proportion of residual acid expelled during flowback) were introduced to quantitatively assess the efficiency of acid invasion and flowback under varying flow rates, viscosities, and the presence or absence of surfactants. The results demonstrate that the invasion coefficient of residual acid increases with the injection rate, while the flowback rate decreases as the injection rate is reduced. A higher viscosity of the oil phase hinders acid invasion and results in slower flowback due to increased flow resistance in the micro model. However, the final flowback rate is higher with a higher viscosity oil phase compared to a lower viscosity phase. The addition of surfactants enhances the efficiency of acid invasion and flowback, increasing the invasion coefficient by up to 5% and the flowback rate by up to 3%.

Keywords: fractured-vuggy carbonate reservoir; residual acid invasion and flowback; microfluidics; two-phase flow (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2025
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