scholarly journals Secondary migration of hydrocarbons in the Zhujiang Formation in the Huixi half-graben, Pearl River Mouth Basin, South China Sea

2016 ◽  
Vol 53 (2) ◽  
pp. 189-201 ◽  
Author(s):  
Junwen Peng ◽  
Xiongqi Pang ◽  
Shuang Xiao ◽  
Huijie Peng ◽  
Qianwen Li ◽  
...  
Keyword(s):  
Physical Properties ◽  
River Mouth ◽  
Source Rocks ◽  
Pearl River ◽  
Pearl River Mouth Basin ◽  
Hydrocarbon Migration ◽  
Source Correlation ◽  
Half Graben ◽  
Porosity And Permeability ◽  
Oil Source

The process and mechanisms of secondary hydrocarbon migration in the Huixi half-graben, Pearl River Mouth Basin, were investigated on the basis of geological analysis of the strata and study of the porosity and permeability of the reservoir rocks, fluid potential, oil properties, and geochemistry of oil–source correlation. The results suggest that the hydrocarbons of the Zhujiang Formation in the Huixi half-graben were derived from source rocks of the Eocene Wenchang Formation and the Eocene–Oligocene Enping Formation in the Huizhou Sag. The hydrocarbons migrated laterally from northeast to southwest. The sandstone in the upper member of the Zhujiang Formation exhibited superior physical properties (porosity and permeability) and connectivity than the lower member. Thin sandstone beds with good physical properties and stable distribution in the upper member of the Zhujiang Formation were the main carrier beds for lateral hydrocarbon migration.

2α-Methylhopane: Indicator for Oil–Source Correlation in the Pearl River Mouth Basin, China

2017 ◽  
Vol 23 (3) ◽  
pp. 185-198 ◽  
Author(s):  
Wanfeng Zhang ◽  
Xiangtao Jiang ◽  
Liling Pang ◽  
Xuanbo Gao ◽  
Shukui Zhu
Keyword(s):  
River Mouth ◽  
Pearl River ◽  
Pearl River Mouth Basin ◽  
Source Correlation ◽  
The Pearl River ◽  
Oil Source

Pressure evolution and hydrocarbon migration in the Baiyun sag, Pearl River Mouth basin, China

2007 ◽  
Vol 1 (2) ◽  
pp. 241-250 ◽  
Author(s):  
Wanzhong Shi ◽  
Honghan Chen ◽  
Changmin Chen ◽  
Xiong Pang ◽  
Ming Zhu
Keyword(s):  
River Mouth ◽  
Pearl River ◽  
Pearl River Mouth Basin ◽  
Hydrocarbon Migration ◽  
Baiyun Sag ◽  
Pressure Evolution

scholarly journals Impact of High Thermal Setting and Fluid Activities on Sandstone Compaction: A Case Study of the Baiyun Sag in the Pearl River Mouth Basin (Northern South China Sea)

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-15
Author(s):  
Chi Li ◽  
Jinglan Luo ◽  
Caiwei Fan ◽  
Shanshan Li ◽  
Shijiu Wu ◽  
...  
Keyword(s):  
South China Sea ◽  
Physical Properties ◽  
South China ◽  
River Mouth ◽  
Geothermal Gradient ◽  
Pearl River ◽  
Pearl River Mouth Basin ◽  
Compaction Process ◽  
The Pearl River ◽  
Static Compaction

Compaction is regarded as central to the reduction of reservoir physical properties. The thermal compaction process controlled by a basin’s heat flow and the static compaction caused by overload on rocks are both important factors controlling the compaction strength. However, porosity loss resulting from thermal and static compaction has not been distinguished. The Baiyun Sag in the Pearl River Mouth Basin in the northern part of the South China Sea with high heat flows and a variable geothermal gradient is an ideal setting for studying the characteristics and mechanisms of the thermal compaction process. The characteristics of compaction and the effect of thermal fluid activities on reservoir physical properties are carried out, based on the observation and identification of sandstone thin sections under a microscope, the measurement and simulation of the temperatures and trapping pressures of fluid inclusions, and the calculation of the compaction porosity loss as well. The result shows that the compaction mode of sandstone reservoirs in the Zhuhai Formation is dominated by static compaction in the LGR (the low geothermal gradient region), whereas the diagenetic process of the Zhuhai Formation in the MGR (the moderate geothermal gradient region) and HGR (the high geothermal gradient region) is affected not only by the static compaction effect but also by the thermal compaction effect caused by abnormal formation temperature and pressure conditions. The porosity loss caused by the thermal compaction ranges from 5.5% to 11.2% with an average of 7.9% and from 4.6% to 16.6% with an average of 10.2% in the MGR and HGR, respectively. The porosity loss caused by the static compaction ranges from 15.9% to 20.8% with an average of 19.4% and from 8.4% to 15.8% with an average of 12.8% in the MGR and HGR, respectively.

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