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热解生烃实验是研究油气生成机理与定量评价烃源岩生烃潜力的重要方法.烃源岩热解生烃模拟结果不仅与温度、压力和时间等因素有关,而且与地层孔隙水及压实成岩作用等地质因素密切相关.采用高压流体和高压釜(低压水蒸气)两种生烃热模拟方法对低成熟海相二叠统大隆组(P2d)黑色泥岩进行了热解生烃实验模拟.对比分析两组实验结果表明地层孔隙热解实验有利于液态油的生成,不利于液态油向气态烃的转化,并极大地提高了干酪根的生油气潜力,显示了高压液态水、流体压力和孔隙空间等地质因素对烃源岩中有机质热成熟生烃反应的重要影响.这种影响可能与高压液态水的近临界特性有关,近临界特性地层水的参与改变了干酪根热力生烃反应的物理化学行为.推断在实际地质温压(100~200℃,30~120MPa)条件下,烃源岩孔隙中的地层水是一种相对低温高压液态水,具有水的近临界物理化学特性,因此高压流体生烃热模拟实验与实际地层情况更为接近,能更有效地评价烃源岩生烃潜力.
Pyrolysis hydrocarbon generation experiment is an important method to study hydrocarbon generation mechanism and quantitatively evaluate hydrocarbon generation potential of hydrocarbon source rock.The pyrolysis hydrocarbon generation simulation results of hydrocarbon source rock are not only related to factors such as temperature, pressure and time, but also with pore water and compaction Diagenesis and other geological factors are closely related.The pyrolysis hydrocarbon generation experiments of the low-mature Permian Dalong Formation (P2d) black mudstone are simulated by using two kinds of hydrocarbon generation heat simulation methods: high pressure fluid and autoclave (low pressure water vapor) The results of two experiments show that the pore pyrolysis experiment is favorable to the formation of liquid oil, which is not conducive to the conversion of liquid oil to gaseous hydrocarbon and greatly enhances the hydrocarbon generation potential of kerogen. It shows that high pressure liquid water, fluid pressure And pore space and other geological factors have an important influence on the thermal maturity of hydrocarbon generation in source rocks, which may be related to the near-critical characteristics of high-pressure liquid water. The formation of near-critical formation water changes the thermal hydrocarbon generation reaction of kerogen The physical and chemical behaviors of the source rocks are deduced from the fact that the formation water in the pores of the source rocks is a kind of relatively low temperature and high pressure liquid water under the condition of actual temperature and pressure (100-200 ℃, 30-120MPa) Water near the critical physicochemical properties, and therefore the high pressure hydrocarbon fluid thermal simulation and the actual situation closer to the formation, can be more effectively evaluate hydrocarbon potential source rocks.