论文部分内容阅读
本实验研究是针对中原桥口油田南八仙浅层桥69-08井注天然气项目进行的。该井油藏温度50℃,原始地层压力10.11 MPa,饱和压力9.43 MPa,脱气原油50℃粘度0.96 mPa.s,20℃密度0.7642 g/cm3,实测油气比200m3/m3。采用PVTsim10.0软件得到模拟油藏相图,表明该油藏为不饱和油藏,在油藏压力下开采时油藏流体以单相渗流,油藏流体临界温度331.6℃,临界压力7.66 MPa。注入气为含甲烷89.3%的油藏深层天然气。用3种方法预测的最小混相压力(MMP)值均大于在CFS-200型混相驱实验装置上通过长1.22 m、内径6.35 mm、渗透率7.5μm2的填砂细管测得的MMP值(18 MPa),偏差在+22.2%~+77.8%。在细管驱替实验中,随注入压力增大(10.11~22.0 MPa),气体突破体积(0.79~0.86 PV)、突破时采出程度(49.8%~74.0%)、最终采出程度(59.0%~91.0%)均增大,即混相驱与非混相驱相比,见气晚而采出程度高;在混相驱中,注入压力的影响较小。图6表2参6。
The experimental study is aimed at the Central Plains Qiaokou South Gas Field shallow buried bridge 69-08 gas injection project. The reservoir temperature is 50 ℃, the original formation pressure is 10.11 MPa, the saturation pressure is 9.43 MPa, the viscosity of degassed crude oil is 0.96 mPa.s at 50 ℃, and the density is 0.7642 g / cm3 at 20 ℃. The measured oil-gas ratio is 200 m3 / m3. The simulated reservoir phase diagram was obtained by PVTsim10.0 software. The result shows that the reservoir is an unsaturated reservoir. When the reservoir is under reservoir pressure, the fluid in the reservoir is seeded by single phase. The critical temperature of the reservoir fluid is 331.6 ℃ and the critical pressure is 7.66 MPa. Injector gas is 89.3% methane deep in natural gas. The minimum miscibility pressure (MMP) values predicted by the three methods were all greater than the MMP values (18) measured by a sand-filled capillary tube with a length of 1.22 m, an inner diameter of 6.35 mm and a permeability of 7.5 μm2 on the CFS- MPa), the deviation of +22.2% ~ +77.8%. In the thin-tube displacement experiment, the gas breakthrough volume (0.79-0.86 PV), the breakthrough rate (49.8% -74.0%) and the final recovery rate (59.0% ~ 91.0%), that is, mixed phase flooding and non-mixed flooding compared to see the gas was late and a high degree of mining; miscible flooding, injection pressure less affected. Figure 6 Table 2 参 6.