Evaluation of geological factors in characterizing fault connectivity during hydrocarbon migration: Application to the Bohai Bay Basin

Zhang, Likuan; Luo, Xiaorong; Vasseur, G.; Yu, Changqing; Yang, Wan; Lei, Yuhong; Song, Chuang; Yu, Lan; Yan, Jingqi

doi:10.1016/j.marpetgeo.2011.06.008

Cited by 35 publications

(16 citation statements)

References 45 publications

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“…Faults can act as conduits and efficient pathways for hydrocarbon migration (Aydin, 2000; Boles et al., 2004; Zhang et al., 2011). Many faults have been found in tight-gas reservoirs, and their distribution, forming mechanism, as well as their control on gas migration and accumulation have been characterized and discussed (Baytok and Pranter, 2013; Fall et al., 2012; Olson et al., 2009; Robert and Suzanne, 2004; Shanley et al., 2004).…”

Section: Resultsmentioning

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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Section: Resultsmentioning

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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“…Previous studies have found that a higher SGR indicates a poorer porosity and permeability in the fault damage zone, and the fault will have good sealing ability when the shale content of the fault zone exceeds 0.7 in the Dongying Depression [34,36].…”

Section: Analysis Of Fault Migration and Sealing Propertiesmentioning

confidence: 97%

“…The current stress field in the Dongying anticline was studied by Zhang et al [36]. The maximum horizontal stress is in the direction of 70…”

Section: Analysis Of Fault Migration and Sealing Propertiesmentioning

confidence: 99%

Geometry, kinematics and dynamic characteristics of a compound transfer zone: the Dongying anticline, Bohai Bay Basin, eastern China

et al. 2016

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Abstract:The Dongying anticline is an E-W striking complex fault-bounded block unit which located in the central Dongying Depression, Bohai Bay Basin. The anticline covers an area of approximately 12 km 2 . The overlying succession, which is mainly composed of Tertiary strata, is cut by normal faults with opposing dips. In terms of the general structure, the study area is located in a compound transfer zone with major bounding faults to the west (Ying 1 fault) and east (Ying -8 and -31 faults). Using three-dimensional seismic data, wireline log and checkshot data, the geometries and kinematics of faults in the transfer zone were studied, and fault displacements were calculated. The results show that when activity on the Ying 1 fault diminished, displacement was transferred to the Ying -8, Ying -31 and secondary faults so that total displacement increased. Dynamic analysis shows that the stress fields in the transfer zone were complex: the northern portion was a left-lateral extensional shear zone, and the southern portion was a right-lateral extensional shear zone. A model of potential hydrocarbon traps in the Dongying transfer zone was constructed based on the above data combined with the observed reservoir rock distribution and the sealing characteristics of the faults. The hydrocarbons were mainly expulsed from Minfeng Sag during deposition pe- riods of Neogene Guantao and Minghuazhen Formations, and migrated along major faults from source kitchens to reservoirs. The secondary faults acted as barriers, resulting in the formation of fault-bound compartments. The high points of the anticline and well-sealed traps near secondary faults are potential targets. This paper provides a reservoir formation model of the low-order transfer zone and can be applied to the hydrocarbon exploration in transfer zones, especially the complex fault block oilfields in eastern China.

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“…However, the Bohai Bay Basin is a faulted basin, and numerous faults developed in the Paleozoic to Cenozoic system which affect the sealing integrity of caprocks to different extent (Jiang et al, 2015). In this case, the vertical distribution of natural gas depends not only on the sealing property of the caprocks, but also on the connecting capacity of a fault for hydrocarbon migration over geological time scales (Aydin, 2000;Zhang et al, 2011;Brogi et al, 2015). In other words, the fault-caprock sealing capacity has a major influence on the vertical distribution of natural gas.…”

Section: Fault-cap Rock Dual Control Vertical Distribution Of Coal-fomentioning

confidence: 99%

Distribution Characteristics and Accumulation Model for the Coal‐formed Gas Generated from Permo‐Carboniferous Coal Measures in Bohai Bay Basin, China: A Review

Jiang

Gluyas

et al. 2019

Acta Geologica Sinica (Eng)

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Coal-formed gas generated from the Permo-Carboniferous coal measures has become one of the most important targets for deep hydrocarbon exploration in the Bohai Bay Basin, offshore eastern China. However, the proven gas reserves from this source rock are remain low to date, and the distribution characteristics and accumulation model for the coalformed gas are not clear. Here we review the coal-formed gas deposits formed from the Permo-Carboniferous coal measures in the Bohai Bay Basin. The accumulations are scattered, and dominated by middle-small sized gas fields, of which the proven reserves ranging from 0.002 to 149.4×10 8 m 3 with an average of 44.30×10 8 m 3 and a mid-point of 8.16×10 8 m 3 . The commercially valuable gas fields are mainly found in the central and southern parts of the basin. Vertically, the coal-formed gas is accumulated at multiple stratigraphic levels from Paleogene to Archaeozoic, among which the Paleogene and Permo-Carboniferous are the main reservoir strata.According to the transporting pathway, filling mechanism and the relationship between source rocks and reservoir, the coal-formed gas accumulation model can be defined into three types: " Upward migrated, fault transported gas" accumulation model, " Laterally migrated, sandbody transported gas" accumulation model, and " Downward migrated, sub-source, fracture transported gas" accumulation model. Source rock distribution, thermal evolution and hydrocarbon generation capacity are the fundamental controlling factors for the macro distribution and enrichment of the coal-formed gas. The fault activity and the configuration of fault and caprock control the vertical enrichment pattern.

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Evaluation of geological factors in characterizing fault connectivity during hydrocarbon migration: Application to the Bohai Bay Basin

Cited by 35 publications

References 45 publications

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

Geometry, kinematics and dynamic characteristics of a compound transfer zone: the Dongying anticline, Bohai Bay Basin, eastern China

Distribution Characteristics and Accumulation Model for the Coal‐formed Gas Generated from Permo‐Carboniferous Coal Measures in Bohai Bay Basin, China: A Review

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