Quantitative evaluation of the reservoir potential and controlling factors of semi-deep lacustrine tempestites in the Eocene Lijin Sag of the Bohai Bay Basin, East China

Wang, Junhui; Jiang, Zaixing; Zhang, Yuanfu; Wei, Xiaojie; Wang, Hang; Liu, Shengqian

doi:10.1016/j.marpetgeo.2016.05.006

Cited by 12 publications

(2 citation statements)

References 53 publications

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“…The permeability range of the reservoir is 0.1-11.457 mD. According to the mercury injection curve in this area, the pore throat radius is mainly distributed between 0.0025μm and 1.5 μm (Song et al, 2012;Wang et al, 2016). Other simulation parameters are shown in Table 3.…”

Section: Figure 14mentioning

confidence: 99%

The injection capacity evaluation of high-pressure water injection in low permeability reservoir: numerical and case study

Zhu,

Gao,

Wang

et al. 2024

Front. Earth Sci.

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Low permeability oil reservoir resources are rich and their efficient development is considered an important way to solve energy security issues. However, the development process of low permeability oil reservoirs is faced with the challenges of insufficient natural energy and rapid production decline. The high-pressure water injection technology is a method that relies on high-pressure and large-volume to inject fluid into the reservoir to replenish energy. It is considered as an important technical means to quickly replenish formation energy. This study focuses on the injection capacity for the high-pressure water injection technology of low permeability oil reservoir. Firstly, the fluid-structure interaction mathematical model for two-phase fluid flow was established. The solution of the mathematical model was then obtained by coupling the phase transport in porous media module and Darcy’s law module on the COMSOL numerical simulation platform. The numerical model established in this study was verified through the Buckley-Leverett model. The study on the injection capacity of high-pressure water injection technology was conducted using the geological background and reservoir physical properties of Binnan Oilfield (Shengli, China). The results show that the production pressure difference is the key factor in determining the injection capacity. When the production pressure difference increases from 5 MPa to 30 MPa, the cumulative injection volume increases by 8.1 times. In addition, sensitivity analysis shows that the injection capacity is significantly influenced by the properties of the reformation area. The effect of these parameters from high to low is as follows: stress sensitivity factor, permeability, rock compressibility, and porosity. Compared to the reformation area, the influence of the physical parameters of the matrix area on the injection capacity is negligible. Therefore, effective reservoir reformation is essential for enhancing the injection capacity. This research provides a theoretical basis for the design and optimization of the high-pressure water injection technology schemes for low permeability oil reservoir.

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Section: Figure 14mentioning

confidence: 99%

The injection capacity evaluation of high-pressure water injection in low permeability reservoir: numerical and case study

Zhu,

Gao,

Wang

et al. 2024

Front. Earth Sci.

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“…[24][25][26][27] The Bohai Bay Basin is a Mesozoic-Cenozoic rift basin which displays a "lazy-Z" pattern. [28][29][30][31] The Nanpu Sag is a typical dustpan-shaped faulted sag ( Figure 1). 1,30,32,33 The Nanpu Sag experienced a rifting stage during the Paleogene and then a postrifting stage since Neogene.…”

Section: Geologic Settingsmentioning

confidence: 99%

In‐situ stress determination and fracture characterization using image logs: The Paleogene Dongying Formation in Nanpu Sag, Bohai Bay Basin, China

Niu

Liu

Lai

et al. 2019

Energy Science & Engineering

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Fracture detection and in‐situ stress determination via well logs are important for exploration and exploitation of subsurface hydrocarbons. Cores, thin sections, and image logs are used to describe and interpret the subsurface fractures and in‐situ stress in the Paleogene Dongying sandstones in Nanpu Sag, Bohai Bay Basin, China. The maximum horizontal stress (SHmax) indicates a nearly east‐west trend according to the borehole breakouts and drilling‐induced fractures. Natural fractures in the Dongying sandstones are classified into: (1) open fractures and (2) closed fractures. The cement‐filled (closed) fractures are commonly detected by image logs as bright discontinuous sinusoidal waves due to resistive filling materials, while the open fractures are evident on image logs appearing as dark sine waves. The open fractures are of dominantly high dip angles, and the rose diagrams confirm the presences of two sets of fractures: northwest‐southeast and northwest‐southeast orientation. Fractures with strikes approximately parallel to the SHmax have good connectedness, making a significant contribution in hydrocarbon production. In addition, the oil‐bearing layers are mainly associated with the intervals with open fractures. The presence of natural fractures provides important pore spaces and fluid flow conduits. Insights can be provided into the subsurface fracture (natural and induced) detection and characterization using image logs.

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An early Eocene subaqueous fan system in the steep slope of lacustrine rift basins, Dongying Depression, Bohai Bay Basin, China: Depositional character, evolution and geomorphology

Zhang

Zhu

Lü

et al. 2019

Journal of Asian Earth Sciences

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Quantitative evaluation of the reservoir potential and controlling factors of semi-deep lacustrine tempestites in the Eocene Lijin Sag of the Bohai Bay Basin, East China

Cited by 12 publications

References 53 publications

The injection capacity evaluation of high-pressure water injection in low permeability reservoir: numerical and case study

The injection capacity evaluation of high-pressure water injection in low permeability reservoir: numerical and case study

In‐situ stress determination and fracture characterization using image logs: The Paleogene Dongying Formation in Nanpu Sag, Bohai Bay Basin, China

An early Eocene subaqueous fan system in the steep slope of lacustrine rift basins, Dongying Depression, Bohai Bay Basin, China: Depositional character, evolution and geomorphology

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