摘要
针对h159断块隔夹层薄、分注难度大的问题及低油价下注水井不宜过多的形势,建议分上下2套层系开展耦合注水试验,以提高油藏采收率和控制成本。运用数值模拟方法研究注采耦合技术政策界限,从注水方式、注水时机、注水周期及注采比等指标逐一甄选,得到最优化的注采耦合方案。结果表明:注水周期为上注30 d,下采45 d(注水井注上套层系的同时对应油井采下套层系)后转为下注30 d,上采45 d,注采比为1.0的方式最佳。考虑措施时间对效益的影响,采取720 d的注采耦合之后恢复常规注采方式得到的利润和经济可采储量最大。注采耦合技术的成功运用表明该技术可在同类型油藏中得到更好推广,从而提高水驱采收率。
Fault-block h159 is characterized by thin interlayers,unfeasible separate injection andlimitation of water injection well number under current oil price. Coupling water injection test with two stratum series is recommended to enhance oil recovery and control cost. Reservoir numerical simulation is used to study the technology policy limits of injection-production coupling and the water injection mode,injection timing,injection period,injection-production ratio and other parameters are respectively optimized to determine the final injection-production coupling program. Research shows that the injection period is upper injection for 30 d and lower production for 45 d( both the upper injection and lower production are simultaneously carried out) in the early stage and the injection period is adjusted to lower injection for 30 d and upper production for 45 d and the optimum injection-production ratio is 1. 0. Considering the effect of treatment period on profit,the maximum profit and economic recoverable reserve can be gained by injection-production coupling for 720 d before adjusting to conventional injection-production mode. This successful application will promote the widely application of injection-production coupling in similar reservoirs and improve waterflooding recovery degree.
出处
《特种油气藏》
CAS
CSCD
北大核心
2016年第3期110-112,156,共3页
Special Oil & Gas Reservoirs
基金
国家自然科学基金"考虑启动条件和井筒压降的底水油藏分支水平井水脊耦合模型"(51404201)
关键词
构造-岩性油藏
注采耦合
周期注采比
数值模拟
h159断块
structural-lithological reservoir
injection-production coupling
cycle injection-production ratio
numerical simulation
Fault-block h159
