Evolution of continental formation pressure in the middle part of the Western Sichuan Depression and its significance on hydrocarbon accumulation

Guo, Yingchun; Pang, Xiongqi; Chen, Dongxia; Ji-gao, Leng; Tian, Jie

doi:10.1016/s1876-3804(12)60062-7

Cited by 23 publications

(5 citation statements)

References 8 publications

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“…Previously, scholars have different divided standards for formation pressure coefficient based on different research content and object (Guo et al, ; Liu et al, ; Xu et al, ). This paper uses the GB/T 26979— 2011 natural gas classification criteria.…”

Section: Characteristics Of Formation Pressure Distributionmentioning

confidence: 99%

“…It becomes a top hot topic for domestic and foreign scholars by analysing the relationship between pressure and natural gas distribution to guide the exploration and discovery of oil and gas reservoirs. Above all, the study of formation pressure is the key as well as the difficulty of gas exploration and study (Du, Zheng, & Jiao, ; Guo, Pang, Chen, Leng, & Tian, ; Liu, Jiang, Song, Cai, & Xu, ; Yang, Yu, Li, & Zhang, ; Zou, Hao, & Cai, ), which runs through the whole process of natural gas exploration and production (Li, Zhang, Li, Xi, & Guo, ; Wang, Sun, Zhang, Li, & Zhang, ; Wang, Wei, Wang, & Li, ; Yao et al, ; Zhang, Chen, Wang, Huang, & Wu, ; Zhang, Zou, Li, Fu, & Wang, ).…”

Section: Introductionmentioning

confidence: 99%

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Evolution of formation pressure and accumulation of natural gas in the Upper Palaeozoic, eastern‐central Ordos Basin, Central China

Zhang

Zhao²

2018

Geological Journal

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The exploration achievements in the eastern‐central Ordos Basin have attracted tremendous attention in recent years. However, only a few studies were carried out on the relationship between formation pressure and distribution of natural gas in this area. The formation pressure of 293 wells, logging data of 154 wells, and fluid inclusion samples of 53 wells were analysed in this paper, and the results show that the mudstones from Permian Upper Shihezi Formation to Permian Taiyuan Formation are mostly undercompacted. Four gas‐bearing layers with significant differences in pressure profile can be further divided into Permian negative pressure system and Carboniferous normal pressure system. The distribution of current formation pressure is high in the east and north areas but low in the west and south areas. The sedimentary facies and distribution of formation pressure in Permian have a good consistency. The vertical development (zonation) of gas reservoirs is controlled by the undercompacted mudstone layers, and the reservoirs can be found in the “low pressure” areas of negative pressure strata in the Permian and “high pressure” regions of normal pressure strata in the Carboniferous. The pressure evolution and accumulation process can be divided into 3 stages: hydrocarbon‐generation supercharging accumulation during Late Jurassic—end of Early Cretaceous, sandstone resilience discharging accumulation during end of Early Cretaceous—Paleogene, and adjusting accumulation during Paleogene—Quaternary. The discovery of the relationship between formation pressure and gas reservoirs is significant to the future natural gas exploration in this area.

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Section: Characteristics Of Formation Pressure Distributionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Evolution of formation pressure and accumulation of natural gas in the Upper Palaeozoic, eastern‐central Ordos Basin, Central China

Zhang

Zhao²

2018

Geological Journal

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“…Within the tight-sand zones, porosity and permeability are enhanced by the development of microfracture networks, caused by tectonic, overpressure, and diagenetic origins (Lyu et al., 2017; Zeng, 2010). In the Shifang area, where faults rarely developed, microfractures mainly formed due to diagenesis and extra-high pore pressure caused by gas charging into the Jurassic intervals (Guo et al., 2012). The microfracture networks primarily serve as an important storage space and fluid-flow channels in the tight sandstones (Lyu et al., 2017).…”

Section: Discussionmentioning

confidence: 99%

Conventionally trapped natural gas accumulations in the Jurassic tight sandstone reservoirs: A case study from the Center of the Western Sichuan Basin, SW China

Guo

Song

Fang

et al. 2017

Energy Exploration & Exploitation

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Tight gas accumulations, commonly characterized by low permeability, low porosity, and complicated pore structure, are widely distributed in the Sichuan Basin. Recent exploration in the Chengdu Sag, Western Sichuan Basin has proven that Jurassic tight-sandstone reservoirs attach significant gas potential. However, long distance migration between source and reservoir intervals entangles understanding of the tight-gas accumulation mechanism. It is unclear whether producible gas in Jurassic intervals is either from ''simple sweet-spots in a continuous accumulation'' or ''conventionally trapped accumulations in low-permeability reservoir rocks''. To identify the regionally active gas system and characterize the charging pattern, a geochemical study was performed by interpreting the gas molecular and carbon isotope compositions in Jurassic and conducting gas-source correlations as well as gas migration distance calculation with the relationship among d 13 C 1 vs. R o vs. H (burial depth). Research results indicate that the Jurassic tight gases in Majing-Shifang areas are coal-derived dry gases generated by the primary cracking of kerogen. Gas/source correlation and gas migration distance calculation reveal that gases are mainly sourced from the Upper Triassic humic source rocks (T 3 x 5 , the fifth member of the Xujiahe Formation). Gas accumulations in the Jurassic Penglaizhen Formation were formed with an original vertical migration of about 2-3 km and then a long-distance lateral migration within tight sand layers, which is verified by the decreasing d 13 C 1 and the general increasing iC 4 /nC 4 in the Penglaizhen Formation. The Jurassic tight-sandstone reservoirs in Majing-Shifang areas occur in low-porosity and low-permeability reservoir rocks in conventional lithological traps, which are not continuous-type gas accumulations or basin-centered gas systems. The faults in Majing area serve as dominant vertical conducting pathway and the relatively permeable

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“…The Xujiahe formation is recognized as a large scale hydrocarbon reservoir which features low to ultra-low porosity and permeability (Guo et al, 2012;Zou et al, 2009), CH 4 from the second group of the Xujiahe formation yields δ 13 C ranging from − 30.3‰ to − 31.97‰ which pertains to coal-derived gas (Wu et al, 2008), the high CH 4 concentration detected in WFSD-1 may come from the coal line bearing mudstone nearby (Fig. 2).…”

Section: Gas Variation Constrained By Lithologymentioning

confidence: 99%

Real-time drilling mud gas monitoring records seismic damage zone from the 2008 Mw7.9 Wenchuan earthquake

Gong

Lao

et al. 2015

Tectonophysics

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Evolution of continental formation pressure in the middle part of the Western Sichuan Depression and its significance on hydrocarbon accumulation

Cited by 23 publications

References 8 publications

Evolution of formation pressure and accumulation of natural gas in the Upper Palaeozoic, eastern‐central Ordos Basin, Central China

Evolution of formation pressure and accumulation of natural gas in the Upper Palaeozoic, eastern‐central Ordos Basin, Central China

Conventionally trapped natural gas accumulations in the Jurassic tight sandstone reservoirs: A case study from the Center of the Western Sichuan Basin, SW China

Real-time drilling mud gas monitoring records seismic damage zone from the 2008 Mw7.9 Wenchuan earthquake

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