Petroleum migration and accumulation in the Bozhong sub-basin, Bohai Bay basin, China: Significance of preferential petroleum migration pathways (PPMP) for the formation of large oilfields in lacustrine fault basins

Hao, Fang; Zou, Huayao; Gong, Zhigang; Deng, Yansha

doi:10.1016/j.marpetgeo.2006.10.007

Cited by 138 publications

(61 citation statements)

References 44 publications

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“…The PL19-3 oilfield lies in the east Bonan low uplift which is surrounded by four sags: the Bozhong and Bodong sags to the north, the Huanghekou sag to the southwest and the Miaoxi sag to the east (Figure 1). Previous studies indicated that all sags contain three source rock intervals, i.e., the third and the first members of Eocene Shahejie Formation (E 2 s 3 and E 2 s 1 ) and the third member of Oligocene Dongying Formation (E 3 d 3 ) [23,26]. All these intervals contain hydrogen-rich organic matters [31][32][33][34].…”

Section: Sufficient Oil Supply From Multiple Kitchens and Multiple Acmentioning

confidence: 99%

“…Therefore, the PL19-3 field provides an excellent natural laboratory for revealing the mechanisms for latestage rapid accumulation in active fault zones [20]. The geochemical origin and geological characteristics of the PL19-3 oilfield have been studied by several investigators [20][21][22][23]. This paper focuses on major factors and processes responsible for late-stage rapid oil accumulation in the PL19-3 field and discusses indicators of rapid, episodic oil accumulation in sedimentary basins.…”

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confidence: 99%

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Late-stage rapid accumulation of the PL19-3 giant oilfield in an active fault zone during Neotectonism in the Bozhong depression, Bohai Bay

Zou

Gong

Teng

et al. 2011

Sci. China Earth Sci.

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Section: Sufficient Oil Supply From Multiple Kitchens and Multiple Acmentioning

confidence: 99%

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confidence: 99%

Late-stage rapid accumulation of the PL19-3 giant oilfield in an active fault zone during Neotectonism in the Bozhong depression, Bohai Bay

Zou

Gong

Teng

et al. 2011

Sci. China Earth Sci.

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“…In the central Junggar Basin, the oil-prone Permian source rocks are within the overpressured system. Petroleum generated from Permian and Jurassic source rocks could migrate laterally through preferential petroleum migration pathways [56,57] and accumulated in structural traps or lithological traps in the overpressured system, forming overpressured petroleum reservoirs (Figure 9). Petroleum generated from the overpressured source rocks could also migrate vertically through faults or hydraulic fractures into the overlying, normally pressured system and accumulate in structural or lithological traps, forming normally pressured petroleum reservoirs.…”

Section: Petroleum Exploration Potentialmentioning

confidence: 99%

“…Commercial petroleum reservoirs could be potentially found in both the overpressured system and the normally pressured system. The focusing of petroleum originating from a large area of the generative kitchens into restricted channels is essential for the formation of large oilfields [19,56,57] .…”

Section: Petroleum Exploration Potentialmentioning

confidence: 99%

Overpressure development and oil charging in the central Junggar Basin, Northwest China: Implication for petroleum exploration

Cai¹

2009

Sci. China Ser. D-Earth Sci.

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The Junggar Basin is one of the largest and most petroliferous superimposed petroleum basins in China. The central depression area has become the frontier field for petroleum exploration. The characteristics of potential source rocks and reservoir sandstones, and the pressure regime in the central Junggar Basin were studied. Permian shales are dominated by hydrogen-rich, oil-prone algal organic matter, and Jurassic mudstones are dominated by hydrogen-poor, higher-plant derived organic matter. These source rocks are widespread and have been mature for hydrocarbon generation, suggesting good to excellent exploration potential, both for crude oils and for natural gases. The deeply buried Jurassic sandstones usually have low porosity and permeability. However, sandstones beneath the Jurassic/Cretaceous unconformity display relatively high porosity and permeability, suggesting that meteoric water leaching had improved the quality of the sandstones. Overpressure developed over much of the central Junggar Basin. The overpressured rocks are characterized by slightly increased interval transit time, low sandstone permeability, increased organic matter maturity, and high relative hydrocarbon-gas contents. Mudstones in the overpressured system have quite the same clay mineral compositions as mudstones in the lower part of the normally pressured system. Overpressure generation in the central Junggar Basin is best to be explained as the result of hydrocarbon generation and fluid retention in low-permeability rocks. Petroleum generated from Permian and Jurassic source rocks could migrate laterally through preferential petroleum migration pathways and accumulated in structural traps or lithological traps in the overpressured system, or migrate vertically through faults/ hydraulic fractures into the overlying, normally pressured system and accumulate in structural or lithological traps. Therefore, commercial petroleum reservoirs could be potentially found in both the overpressured system, and in the normally pressured system. pressure regime, overpressure generation, oil charge, petroleum exploration potential, Junggar BasinAs petroleum exploration and development in Cenozoic lacustrine basins increases, finding oil and gas reserves in superimposed basins has become an important strategy in China [1,2] . Superimposed basins refer to sedimentary basins that resulted either from the contemporaneous composition of different proto-type basins or from the superimposition of proto-type basins of different stages [3] . The Junggar Basin, which began to develop in Carboniferous, is one of the largest and most petroliferous superimposed sedimentary basins in China. So far over 20 major oil fields have been found in the basin. These fields had produced a total oil output of over 2×10 8 t by the end of 2005 [4] .Up to the present, most commercial oil and gas fields were found in basin margins or on the uplifts in the Junggar Basin. As petroleum exploration in basin margins and uplift areas goes into the mature phase, finding

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“…However, the nature of petroleum migration pathway is still controversial. Some researchers [7][8][9][10][11][12][13][14][15][16][17][18][19][20][21][22][23][24][25][26] believed that the petroleum fluids migration is mainly driven by structural morphology, and modeling of petroleum fluids migration pathways can be a powerful tool to reduce exploration risk. Others [27][28][29][30][31] propose that petroleum fluids tend to pass through a high-permeable, thin sandstone bed than through a low-permeable and thick sandstone bed, controlled by the heterogeneity of the porosity and permeability of the carrier beds.…”

Section: Introductionmentioning

confidence: 99%

Reconstruction of the Cenozoic History of Hydrocarbon Fluids from Rifting Stage to Passive Continental Margin Stage in the Huizhou Sag, the Pearl River Mouth Basin

Jiang²,

Jiang

et al. 2017

Geofluids

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The Eocene lacustrine sediments are the primary source rocks in the Huizhou Sag of the Pear River Mouth Basin. This study employs basin modeling for four representative wells and two profiles in the Huizhou Sag to reconstruct the process of generation, expulsion, migration, and accumulation of hydrocarbon fluids. The Eocene source rocks started to generate hydrocarbon at 33.9 Ma and are currently in a mid-mature and postmature stage. Hydrocarbons are mainly expelled from the Eocene Wenchang Fm, and the contribution of the Eocene Enping formation is minor. Under the driving forces of buoyancy and excess pressure, major hydrocarbons sourced from the Eocene source rocks firstly migrated laterally to the adjacent Eocene reservoirs during the postrift stage, then vertically via faults to Oligo-Miocene carrier beds, and finally laterally to the structural highs over a long distance during the Pliocene-Quaternary Neotectonic stage, which is controlled by both structural morphology and heterogeneity of carrier beds. Fault is the most important conduit for hydrocarbon fluid migration during the Neotectonic stage. Reactivation of previous faults and new-formed faults caused by the Dongsha Movement (9.8-4.4 Ma) served as vertical migration pathways after 10.0 Ma, which significantly influenced the timing of hydrocarbon accumulation in the postrift traps.

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Petroleum migration and accumulation in the Bozhong sub-basin, Bohai Bay basin, China: Significance of preferential petroleum migration pathways (PPMP) for the formation of large oilfields in lacustrine fault basins

Cited by 138 publications

References 44 publications

Late-stage rapid accumulation of the PL19-3 giant oilfield in an active fault zone during Neotectonism in the Bozhong depression, Bohai Bay

Late-stage rapid accumulation of the PL19-3 giant oilfield in an active fault zone during Neotectonism in the Bozhong depression, Bohai Bay

Overpressure development and oil charging in the central Junggar Basin, Northwest China: Implication for petroleum exploration

Reconstruction of the Cenozoic History of Hydrocarbon Fluids from Rifting Stage to Passive Continental Margin Stage in the Huizhou Sag, the Pearl River Mouth Basin

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