基于机理模型的储气库排水扩容数值模拟
1. 中石油, 辽河油田分公司研究院, 辽宁盘锦 124010
2. 中国地质大学 (武汉), 资源学院, 湖北武汉 430074
| 摘 要： | 水淹油气藏建库在国外已有先例，国内还没有同类型储气库建设的成功经验。本文以辽河油田M19块强水淹层状气顶油藏改建储气库为例开展储气库排水扩容数值模拟研究，解决强水淹条件下如何优化井网设计、优选调峰时机，以解决高效排水逐步形成有效储气空间的技术难题。论文以气藏数值模拟技术为手段，应用机理模型建立储气库排水扩容数值模型，通过多种方案比选，分别讨论了注采井网、水平井位、射孔层位、注采时机、周期注气量等因素对排水量、原油采收率的影响，对影响气液界面运动和驱液效果的各种因素进行了模拟研究，分析了在气驱排液条件下油气水运移机理。模拟结果表明：九点法注采井网，水平井高点注气，水平井上层射孔、直井下层射孔的状态下，累积排水、累积产油、最终采出程度最大，且累积产油量、累积排水量与注气量呈正相关关系，说明这种井网方式下驱替效率更高，波及体积更大，更有利于气驱排水。采用注气排液4个月，注气憋压3个月，平衡期1个月，产气4个月，布九点法井网，水平井高点注气，生产井低层位射孔排液，六个周期循环注采后，排液效果最好，能提高原油采收率5%，在运行压力许可范围内现有月均注气量可提高至1.2倍。该研究成果将进一步指导M19储气库高效排水建库方式设计，不仅可以达到建库的目的，同时可以提高原油采收率，实现效益双赢，还能为同类储气库建设提供借鉴。 |
| 关 键 词： | 强水淹层状气顶油藏; 机理模型; 储气库; 数值模拟 |
| DOI： | 10.57237/j.jest.2022.01.002 |
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收稿日期: 2022-10-03
接受日期: 2022-11-07
在线出版日期: 2022-12-01
Numerical Simulation of Draining and Expanding of Gas Storage Based on Mechanism Model
1. Research Institute of Liaohe Oilfield, CNPC, Panjin 124010, China
2. School of Earth Resources, China University of Geosciences, Wuhan 430074, China
| Abstract: | There are precedents for the construction of flooded hydrocarbon reservoir into gas storage abroad, but there is no successful experience of the same type of gas storage in China. This paper takes the reconstruction of gas-cap oil reservoir with strong water flooded layer into gas storage in Block M19 of Liaohe Oilfield as an example to carry out numerical simulation research on drainage and expansion of gas storage, so as to solve how to optimize well pattern design and peak timing under the strong water flooding conditions, and to solve the technical difficulties of efficient drainage and gradually form effective gas storage space. This paper by means of gas reservoir numerical simulation technology, establishes a numerical model of drainage and expansion of gas storage by applying the mechanism model. Through a variety of alternatives, discusses the influence of well pattern, horizontal well location, perforating horizon, Injection timing, injection volume and other factors on water discharge and crude oil recovery. And conduct a simulation study of various factors affecting the movement of gas liquid interface and displacement effect. The simulation results show that the cumulative water production, cumulative oil production and final oil recovery are the largest under the conditions of nine-spot pattern, gas injection at the high point of formation, perforation at the upper level of the horizontal well and perforation at the lower level of the vertical well, and the accumulated oil production rate and accumulated water production rate are positively correlated with the gas injection rate. It shows that under this well pattern, the displacement efficiency is higher, the sweep volume is larger, and it is more conducive to air-driven drainage. Gas injection and drainage for 4 months, gas injection and pressure holding for 3 months, equilibrium period for 1 month, gas production for 4 months, nine-spot well pattern, gas injection at the high point of formation, perforation and drainage at the lower level of the production well, after six cycles of circular injection and production, the drainage effect is the best, which can increase the final oil recovery by 5%.The gas injection rate can be increased to 1.2 times within the permitted operating pressure. The research results will further guide the design of efficient drainage construction method for M19 gas storage, which can not only achieve the purpose of gas storage construction, but also improve crude oil recovery and achieve win-win benefits, and provide reference for the construction of similar gas storage. |
| Keywords: | Gas-Cap Oil Reservoir with Strong Water Flooded Layer; Mechanism Model; Gas Storage; Numerical Simulation |
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