Significant progress of continental petroleum geological theory in basins of Central and Western China

Jia, Chengzao; Zou, Caineng; Zhi, Yang; Zhu, Rixiang; Chen, Zhuxin; Zhang, Bin; Jiang, Lin

doi:10.1016/s1876-3804(18)30064-8

Cited by 87 publications

(30 citation statements)

References 14 publications

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“…(1) The natural core is put into the triaxial stress machine. (2) The cores are subjected to a triaxial load to induce fractures, and the fracture opening pressure and fracturing pressure are recorded. (3) The core is loaded to an axial pressure between the fracture opening pressure and fracturing pressure.…”

Section: Preparation Of Fractured Cores Because It Ismentioning

confidence: 99%

“…The fractured core is vacuumed for 4 hours and saturated with simulated formation water to measure porosity. (2) The oil is driven out by water until the core no longer produces water, and the initial oil saturation is calculated.…”

Section: Core Displacement Experiment (1)mentioning

confidence: 99%

“…Taking China as an example, most of the newly discovered reservoirs are low-permeability reservoirs. Currently, oil reserves in low-permeability oilfields account for approximately 40% of oil resources and have considerable exploitation potential [1][2][3]. Generally, lowpermeability oilfields have naturally developed fractures that form connected channels [4].…”

Section: Introductionmentioning

confidence: 99%

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The experimental investigation of the HPAM/phenolic resin deep profile system in fractured low-permeability reservoirs

2021

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The problem of injected water channeling along fractures exists in the process of water injection in fractured low permeability reservoir, aimed at this problem, deep profile control technology applies to plug fractures to improve the recovery of low permeability reservoir. In this paper, partially hydrolyzed polyacrylamide (HPAM) is used as water-plugging/profile-modifying agent and phenolic resin as crosslinker agent. Several profile control systems are tested to find the one which is suitable for fractured low permeability reservoirs. The performances of profile control systems are evaluated, and effects of formation water salinity, that of shearing rate and that of temperature on the performance are studied. Finally, in order to study effects of this profile control system on displacing oil, flowability experiment and core displacement experiment are applied. It shows that with the increase of salinty of prepared water and the increase of the shearing rate, the viscosity of this system decreases. With the increase of temperature, the gelling time shortens, the viscosity increases, but the stability weekens. This kind of profile control system has a good effect on plugging fractures of low permeability cores. After water flooding, this kind of profile control system is injected into cores, the recovery ratio can increase 3.5%. So the profile control system composed of HPAM/ phenolic resin can apply to deep profile control in fractured low permeability reservoir to enhance oil recovery.

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Section: Preparation Of Fractured Cores Because It Ismentioning

confidence: 99%

Section: Core Displacement Experiment (1)mentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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The experimental investigation of the HPAM/phenolic resin deep profile system in fractured low-permeability reservoirs

2021

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“…Chang 6 and Chang 8 in the Yanchang Formation are the key blocks for unconventional oil and gas development in China. 5 Tight sandstone usually has complex pore structures and wide micro-and nanopore size distributions, which are quite different from the physical properties of conventional sandstone. 6,7 Although there are various pore structure analysis techniques, NMR and RCP have been widely used to characterize the pore structure and physical properties of tight sandstones.…”

Section: Introductionmentioning

confidence: 99%

Fractal Analysis of Tight Sandstone Petrophysical Properties in Unconventional Oil Reservoirs with NMR and Rate-Controlled Porosimetry

et al. 2021

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Characterization of the pore size distribution of tight sandstone is of great significance for the effective development of tight oil resources. This paper analyzed the fractal characteristics of pore spaces of tight sandstones from the Yanchang Formation in the Ordos Basin of China with NMR and rate-controlled porosimetry (RCP). A new NMR fractal analysis method that considers the movable fluid distribution was proposed. Compared with the conventional NMR fractal analysis metrics, the fractal dimensions of the pore spaces occupied by completely movable fluid and partially movable fluid have stronger correlations with the tight sandstone petrophysical properties. This work shows that the fractal dimensions of pore spaces with partially movable and completely movable fluids are negatively correlated with the permeability and reservoir quality index (RQI), and as the fractal dimensions approach 3, the tight sandstone petrophysical properties become less favorable. The fractal dimensions of the pore spaces detected by RCP were calculated with three different fractal models, the thermodynamic model, the 3D capillary model, and the wetting phase model. The research results show that compared with the results of the other two fractal models, the fractal dimensions obtained from the 3D capillary model can be used to more accurately evaluate tight sandstone petrophysical properties, and the calculated fractal dimensions are strongly negatively correlated to the pore radius, sorting coefficient, skewness, and permeability. The fractal dimensions obtained from the thermodynamic model have no obvious relationship with the tight sandstone properties, and the wetting phase model gives opposite fractal analysis results, so these two fractal models are not recommended for fractal analysis of tight sandstone pore size distributions via RCP. Finally, the models for predicting tight sandstone permeability with NMR and RCP were evaluated and screened.

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“…Rapid growth of the global demand for petroleum and gas resources has promoted exploration and development recently (International Energy Agency, 2011;Wang et al, 2015). Furthermore, with the successful development of shale gas in China, the exploration of shale oil has also been actively promoted (Jia et al, 2018;Sun et al, 2019;Zhang et al, 2020). The resource potential of shale oil in China has been verified and has mainly occurred in continental strata (such as the Cretaceous formation of the Songliao Basin, the Upper Permian formation of the Junggar Basin and the Santanghu Basin, and the Upper Triassic formation of the Ordos Basin) (Liu et al, 2012;Zou et al, 2013;Gao et al, 2016).…”

Section: Introductionmentioning

confidence: 99%

Modeling of Tectonic-Thermal Evolution of Cretaceous Qingshankou Shale in the Changling Sag, Southern Songliao Basin, NE China

Liu

Cheng

et al. 2021

Front. Earth Sci.

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A series of significant shale oil discoveries have been made recently in the Upper Cretaceous Qingshankou Formation in the Songliao Basin, providing a new resource target for shale oil exploration in Northeast China. In this context, an understanding of the tectonic-thermal evolution and maturation history of the Qingshankou Formation is of great significance for shale oil exploration and evaluation. In this study, the thermal history of the Qingshankou Formation since the Late Cretaceous was reconstructed using the paleothermal indicator method. The results indicate that two stages of thermal evolution exist in the southern part of the Songliao Basin: 1) the gradual heating stage during the Late Cretaceous; the heat flow gradually increases during this period and reaches a maximum heat flow value at the end of the Cretaceous. 2) The decline stage since the Neogene; the tectonic activity is relatively stable and the geothermal heat flow is gradually reduced, and the present-day heat flow ranges from 60.1 to 100.7 mW/m2, with an average of 78.2 mW/m2. In addition, the maturity history of the organic-rich shale was reconstructed based on the new thermal history. The Cretaceous Qingshankou shales underwent deep burial thermal metamorphism at the end of the Cretaceous, whereas thermal has faded since the Neogene. The hydrocarbon generation and migration since the Late Cretaceous period of K2qn1 were modeled based on the maturity model. Two main cooling events took place in the late Nenjiang period and the late Mingshui period in the Changling sag. These two tectonic events controlled the structural style and the formation of shale oil reservoirs in the southern Songliao Basin.

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Significant progress of continental petroleum geological theory in basins of Central and Western China

Cited by 87 publications

References 14 publications

The experimental investigation of the HPAM/phenolic resin deep profile system in fractured low-permeability reservoirs

The experimental investigation of the HPAM/phenolic resin deep profile system in fractured low-permeability reservoirs

Fractal Analysis of Tight Sandstone Petrophysical Properties in Unconventional Oil Reservoirs with NMR and Rate-Controlled Porosimetry

Modeling of Tectonic-Thermal Evolution of Cretaceous Qingshankou Shale in the Changling Sag, Southern Songliao Basin, NE China

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