Evidence from such diverse fields as geology,seismology and geophysic exploration indicate that the "backarc spnding"and"terrane matching" models can not be reasonably used to explain the evolution...Evidence from such diverse fields as geology,seismology and geophysic exploration indicate that the "backarc spnding"and"terrane matching" models can not be reasonably used to explain the evolutionary feature of the East China Sea (ECS) Basin. A new model,the persistent extending-pulsative compressing (PEPC) model,is proposed by the authors. An active persistently extension oceanward took place at the margin of the continental lithosphere,because of its inhomogeneous composition,texture and thermal state, and was conttolled by deep-seated (mantle) geological processes.The extension is the main cause for the formation and evolution of the ECS Basin.The northwestward movement of the Philippine Sea lithosphete provides the basin with a compre8sion.The compression is short in time but powerful in force strength, i. e. in a pulsative form, relatively to the above-mentioned extension. The PEPC model plays a new role in comprehencing the laws of hydtocarbon accumulation and prospecting for oil /Ras fields in the ECS Basin.There are several source- reservoir-caprock associations related closely to the multiperiodic persistent extending-pulsative compressing.The Paleocene and Eocene are the main mature source rocks and the Oligocene to Miocene are the potential source rocks in the Shelf Basin.Commonly the persistent extension is favourable to the formation of the hydrocarbon areas, but the pulsative compression causes them to be destroyed.展开更多
Hydrocarbon distribution rules in the deep and shallow parts of sedimentary basins are considerably different, particularly in the following four aspects. First, the critical porosity for hydrocarbon migration is much...Hydrocarbon distribution rules in the deep and shallow parts of sedimentary basins are considerably different, particularly in the following four aspects. First, the critical porosity for hydrocarbon migration is much lower in the deep parts of basins： at a depth of 7000 m, hydrocarbons can accumulate only in rocks with porosity less than 5%. However, in the shallow parts of basins （i.e., depths of around 1000 m）, hydrocarbon can accumulate in rocks only when porosity is over 20%. Second, hydrocarbon reservoirs tend to exhibit negative pressures after hydrocarbon accumulation at depth, with a pressure coefficient less than 0.7. However, hydrocarbon reservoirs at shallow depths tend to exhibit high pressure after hydrocarbon accumulation. Third, deep reservoirs tend to exhibit characteristics of oil （-gas）-water inversion, indicating that the oil （gas） accumulated under the water. However, the oil （gas） tends to accumulate over water in shallow reservoirs. Fourth, continuous unconventional tight hydrocarbon reservoirs are distributed widely in deep reservoirs, where the buoyancy force is not the primary dynamic force and the caprock is not involved during the process of hydrocarbon accumulation. Conversely, the majority of hydrocarbons in shallow regions accumulate in traps with complex structures. The results of this study indicate that two dynamic boundary conditions are primarily responsible for the above phenomena： a lower limit to the buoyancy force and the lower limit of hydrocarbon accumulation overall, corresponding to about 10%-12% porosity and irreducible water saturation of 100%, respectively. These two dynamic boundary conditions were used to divide sedimentary basins into three different dynamic fields of hydrocarbon accumulation： the free fluid dynamic field, limit fluid dynamic field, and restrain fluid dynamic field. The free fluid dynamic field is located between the surface and the lower limit of the buoyancy force, such that hydrocarbons in this field migrate and accumulate展开更多
文摘Evidence from such diverse fields as geology,seismology and geophysic exploration indicate that the "backarc spnding"and"terrane matching" models can not be reasonably used to explain the evolutionary feature of the East China Sea (ECS) Basin. A new model,the persistent extending-pulsative compressing (PEPC) model,is proposed by the authors. An active persistently extension oceanward took place at the margin of the continental lithosphere,because of its inhomogeneous composition,texture and thermal state, and was conttolled by deep-seated (mantle) geological processes.The extension is the main cause for the formation and evolution of the ECS Basin.The northwestward movement of the Philippine Sea lithosphete provides the basin with a compre8sion.The compression is short in time but powerful in force strength, i. e. in a pulsative form, relatively to the above-mentioned extension. The PEPC model plays a new role in comprehencing the laws of hydtocarbon accumulation and prospecting for oil /Ras fields in the ECS Basin.There are several source- reservoir-caprock associations related closely to the multiperiodic persistent extending-pulsative compressing.The Paleocene and Eocene are the main mature source rocks and the Oligocene to Miocene are the potential source rocks in the Shelf Basin.Commonly the persistent extension is favourable to the formation of the hydrocarbon areas, but the pulsative compression causes them to be destroyed.
基金supported by the National Basic Research Program of China (Grant No: 2011CB201100)
文摘Hydrocarbon distribution rules in the deep and shallow parts of sedimentary basins are considerably different, particularly in the following four aspects. First, the critical porosity for hydrocarbon migration is much lower in the deep parts of basins： at a depth of 7000 m, hydrocarbons can accumulate only in rocks with porosity less than 5%. However, in the shallow parts of basins （i.e., depths of around 1000 m）, hydrocarbon can accumulate in rocks only when porosity is over 20%. Second, hydrocarbon reservoirs tend to exhibit negative pressures after hydrocarbon accumulation at depth, with a pressure coefficient less than 0.7. However, hydrocarbon reservoirs at shallow depths tend to exhibit high pressure after hydrocarbon accumulation. Third, deep reservoirs tend to exhibit characteristics of oil （-gas）-water inversion, indicating that the oil （gas） accumulated under the water. However, the oil （gas） tends to accumulate over water in shallow reservoirs. Fourth, continuous unconventional tight hydrocarbon reservoirs are distributed widely in deep reservoirs, where the buoyancy force is not the primary dynamic force and the caprock is not involved during the process of hydrocarbon accumulation. Conversely, the majority of hydrocarbons in shallow regions accumulate in traps with complex structures. The results of this study indicate that two dynamic boundary conditions are primarily responsible for the above phenomena： a lower limit to the buoyancy force and the lower limit of hydrocarbon accumulation overall, corresponding to about 10%-12% porosity and irreducible water saturation of 100%, respectively. These two dynamic boundary conditions were used to divide sedimentary basins into three different dynamic fields of hydrocarbon accumulation： the free fluid dynamic field, limit fluid dynamic field, and restrain fluid dynamic field. The free fluid dynamic field is located between the surface and the lower limit of the buoyancy force, such that hydrocarbons in this field migrate and accumulate
