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选用了某油田的２０块天然岩心，每组２块分１０组分别采用非稳定流方法和稳定流方法进行了油水相对渗透率的平行对比测定。每组平行样品的孔隙度、渗透率基本相同，油驱水建立的束缚水也基本相同（说明孔隙结构基本相同），在同样的条件下进行了老化。实验结果表明，稳定流方法与非稳定流方法所得结果并不吻合。就水相的端点值而言，部分是基本相同的，而大部分情况下稳定流方法测得的水相端点相对渗透率比非稳定流的要低，而且明显地受岩心渗透率大小的影响。目前有一种观点认为低渗透率岩心的水相端点相对渗透率抬不起来，本实验结果表明事实并非如此，可能与没有老化或采用的实验方法有关。研究表明，对于该油田的岩心，稳定流方法与非稳定流方法测得的油水相对渗透率有较大的差别。
20 natural cores of an oilfield were selected. Two groups of 10 natural cores were used for parallel comparison of relative permeability of oil and water using unsteady flow method and steady flow method respectively. The porosity and permeability of each parallel sample are basically the same, and the irreducible water established by oil flooding is basically the same (indicating that the pore structure is basically the same), and aging under the same conditions. The experimental results show that the results obtained by the steady flow method and unsteady flow method do not coincide. In terms of the endpoint values of the water phase, the sections are essentially the same, whereas in most cases the steady-state flow method has a lower relative end-point relative permeability than the unsteady flow and is significantly affected by the core permeability . At present, there is a view that the relative permeability of water-phase endpoints in low-permeability cores can not be lifted. The results of this experiment show that this is not the case and may be related to experimental methods that are not aged or used. The results show that there is a great difference between the relative permeability of oil and water measured by steady flow method and unsteady flow method for the core of this oilfield.