Feasibility of Advanced CO[sub.2] Injection and Well Pattern Adjustment to Improve Oil Recovery and CO[sub.2] Storage in Tight-Oil Reservoirs

• Published in: Processes 2023-10, Vol.11 (11)
• Main Authors: Zhang, Lijun, Sun, Tianwei, Han, Xiaobing, Shi, Jianchao, Zhang, Jiusong, Tang, Huiting, Yu, Haiyang
• Format: Article
• Language: English
• Subjects: Numerical analysis; Petroleum mining; Simulation methods
• ISSN: 2227-9717; 2227-9717
• DOI: 10.3390/pr11113104

Global tight-oil reserves are abundant, but the depletion development of numerous tight-oil reservoirs remains unsatisfactory. CO[sub.2] injection development represents a significant method of reservoir production, potentially facilitating enhanced oil recovery (EOR) alongside CO[sub.2] storage. Currently, limited research exists on advanced CO[sub.2] injection and well pattern adjustment aimed at improving the oil recovery and CO[sub.2] storage within tight-oil reservoirs. This paper focuses on the examination of tight oil within the Ordos Basin. Through the employment of slim-tube experiments, long-core displacement experiments, and reservoir numerical simulations, the near-miscible pressure range and minimum miscible pressure (MMP) for the target block were ascertained. The viability of EOR and CO[sub.2] sequestration via advanced CO[sub.2] injection was elucidated, establishing well pattern adjustment methodologies to ameliorate CO[sub.2] storage and enhance oil recovery. Simultaneously, the impacts of the injection volume and bottom-hole pressure on the development of advanced CO[sub.2] injection were explored in further detail. The experimental results indicate that the near-miscible pressure range of the CO[sub.2]–crude oil in the study area is from 15.33 to 18.47 MPa, with an MMP of 18.47 MPa, achievable under reservoir pressure conditions. Compared to continuous CO[sub.2] injection, advanced CO[sub.2] injection can more effectively facilitate EOR and achieve CO[sub.2] sequestration, with the recovery and CO[sub.2] sequestration rates increasing by 4.83% and 2.29%, respectively. Through numerical simulation, the optimal injection volume for advanced CO[sub.2] injection was determined to be 0.04 PV, and the most favorable bottom-hole flowing pressure was identified as 10 MPa. By transitioning from a square well pattern to either a five-point well pattern or a row well pattern, the CO[sub.2] storage ratio significantly improved, and the gas–oil ratio of the production wells also decreased. Well pattern adjustment effectively supplements the formation energy, extends the stable production lives of production wells, and increases both the sweep efficiency and oil recovery. This study provides theoretical support and serves as a reference for CO[sub.2] injection development in tight-oil reservoirs.