摘要
用胜利油区孤东油田 7 44 检 2 45等井样品进行油水两相渗流规律单因素影响实验 ,结果表明 :净上覆压力增大改变孔隙结构 (主要影响喉道 ) ,水相相对渗透率上升较快而油相相对渗透率下降较快 ,是影响渗流规律主要的因素 ;温度增高改变油水黏度比 ,使束缚水饱和度增大、残余油饱和度减小 ,但在相同油水黏度比条件下 ,温度升高对相对渗透率的影响很小 ;在 3 0MPa、80℃条件下 ,精制油与盐水、脱水脱气原油与盐水的油水黏度比相近 ,含气原油与盐水的油水黏度比略高 ,三者相对渗透率曲线形态相近 ,含气原油与盐水的水相相对渗透率略高于脱水脱气原油与盐水的。用胜利油区 5个油田不同层位的样品 ,进行地层与地面条件下相对渗透率测定对比实验的结果 ,地层条件下的束缚水饱和度高、两相区窄、油水两相前缘含水饱和度低、含水上升快以及最终水相相对渗透率高 ;地层条件下的水驱油效率在注水初期高于地面条件 ,达到一定的注入倍数后低于地面条件 ,最终水驱油效率小于地面条件。进行相对渗透率实验研究时 ,应该模拟油藏条件 ,由于渗流特性对上覆压力和孔隙压力的绝对值不敏感 ,可以只模拟油藏的净上覆压力。图 6表 1参
The experimental results on oil water relative permeability, by using core samples from the Well 7 44 J245 in the Gudong Oilfield of Shengli petroliferous area, reveal that an increase in net overburden pressure led to changes in pore structure (mainly the pore throat), and the water permeability increases more rapidly relative to oil permeability which decreases more rapidly than water permeability. This is the major factor affecting percolation. Temperature increase will also change the oil water viscosity ratio, leading to a higher irreducible water saturation but a lower residual oil saturation. However, temperature has little impact on relative permeability when oil water viscosity ratio is close to 1. At 30MPa and 80℃, the water oil viscosity ratios of refined oil/brine and degassed dehydrated oil/brine are close. Natural reservoir conditions should be simulated during the relative permeability experiment. The experiment can be designed to simulate only the net overburden because percolation is not sensitive to the absolute values of overburden and pore pressure.
出处
《石油勘探与开发》
SCIE
EI
CAS
CSCD
北大核心
2003年第4期102-104,共3页
Petroleum Exploration and Development
关键词
油田开发
油水相对渗透率
地层条件
油水两相渗流
oilfield development
oil water relative permeability
formation condition
two phase percolation of oil and water
