松辽盆地北部致密砂岩储集层原油可动性影响因素
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摘要
以松辽盆地北部上白垩统青山口组高台子和扶余油层致密油为例,在核磁共振、高压压汞等分析的基础上,首次采用二氧化碳超临界驱替和超临界萃取实验方法,对不同岩性、不同含油级别的致密砂岩储集层原油可动性开展了定量研究。实验表明,在模拟松辽盆地北部致密油储集层温度76～89℃、压力35～42 MPa地层条件下,可动油启动时的孔隙度下限为4.4%,渗透率下限为0.015×10~(-3)μm~2,平均孔喉半径下限为21 nm。提出了致密砂岩储集层3种类型划分标准,Ⅰ类储集层可动流体饱和度大于40%,可动油率(可动油量占总油量的比)大于30%,启动压力梯度为0.3～0.6 MPa/m;Ⅱ类储集层可动流体饱和度为10%～40%,可动油率为5%～30%,启动压力梯度为0.6～1.0 MPa/m;Ⅲ类储集层可动流体饱和度一般小于10%,可动油率小于5%,启动压力大于1.0 MPa/m。致密砂岩储集层流体可动性主要受成岩作用和沉积作用影响,埋深小于2 000 m时以Ⅰ类储集层为主,大于2 000 m时主要为Ⅰ类、Ⅱ类储集层;三角洲内前缘相Ⅰ类储集层发育,三角洲外前缘和滨浅湖相以Ⅱ、Ⅲ类储集层为主。
Taking tight oil in Gaotaizi and Fuyu oil layers of the Upper Cretaceous Qingshankou Formation in northern Songliao Basin as an example,based on analyses of nuclear magnetic resonance and high pressure mercury injection,experiment methods of supercritical carbon dioxide displacement and extraction are firstly employed to quantify crude oil mobility in tight sand reservoirs with different lithologies and oil contents.The results show that,under the conditions of simulating the Cretaceous Qingshankou Formation in the northern part of the Songliao Basin at a temperature of 76-89℃and a pressure of 35-42 MPa,the lower limit of the porosity of the movable oil is 4.4%,and the lower limit of the permeability is 0.015×10~(-3)μm~2.The lower limit of the average pore throat radius is 21 nm.On this basis,a classification standard for three types of tight sand reservoirs is proposed.Type I reservoirs are characterized by the movable fluid saturation larger than 40%,the movable oil ratio(ratio of movable oil to total oil)greater than 30%and the starting pressure gradient in the range of 0.3-0.6 MPa/m;Type II reservoirs are characterized by the movable fluid saturation in the range of10%–40%,the movable oil ratio in the range of 5%–30%and the starting pressure gradient in the range of 0.6–1.0 MPa/m;Type III reservoirs are characterized by the movable fluid saturation less than 10%in general,the movable oil ratio less than 5%,and the starting pressure gradient greater than 1.0 MPa/m.The fluid mobility in tight sand reservoirs is mainly affected by diagenesis and sedimentary environment.Reservoirs with depth lower than 2 000 m are dominated by type I reservoir,whereas those with greater depth are dominated by type I and II reservoirs.Reservoirs in inner delta-front facies are dominated by type I reservoir,whereas those in outer delta-front facies and shore-shallow lacustrine facies are dominated by type II and III reservoirs.
Taking tight oil in Gaotaizi and Fuyu oil layers of the Upper Cretaceous Qingshankou Formation in northern Songliao Basin as an example,based on analyses of nuclear magnetic resonance and high pressure mercury injection,experiment methods of supercritical carbon dioxide displacement and extraction are firstly employed to quantify crude oil mobility in tight sand reservoirs with different lithologies and oil contents.The results show that,under the conditions of simulating the Cretaceous Qingshankou Formation in the northern part of the Songliao Basin at a temperature of 76-89℃and a pressure of 35-42 MPa,the lower limit of the porosity of the movable oil is 4.4%,and the lower limit of the permeability is 0.015×10~(-3)μm~2.The lower limit of the average pore throat radius is 21 nm.On this basis,a classification standard for three types of tight sand reservoirs is proposed.Type I reservoirs are characterized by the movable fluid saturation larger than 40%,the movable oil ratio(ratio of movable oil to total oil)greater than 30%and the starting pressure gradient in the range of 0.3-0.6 MPa/m;Type II reservoirs are characterized by the movable fluid saturation in the range of10%–40%,the movable oil ratio in the range of 5%–30%and the starting pressure gradient in the range of 0.6–1.0 MPa/m;Type III reservoirs are characterized by the movable fluid saturation less than 10%in general,the movable oil ratio less than 5%,and the starting pressure gradient greater than 1.0 MPa/m.The fluid mobility in tight sand reservoirs is mainly affected by diagenesis and sedimentary environment.Reservoirs with depth lower than 2 000 m are dominated by type I reservoir,whereas those with greater depth are dominated by type I and II reservoirs.Reservoirs in inner delta-front facies are dominated by type I reservoir,whereas those in outer delta-front facies and shore-shallow lacustrine facies are dominated by type II and III reservoirs.
引文
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