Geological Features and Reservoiring Mode of Shale Gas Reservoirs in Longmaxi Formation of the Jiaoshiba Area

Guo, Xusheng; Hu, Dongfeng; Li, Yuping; Liu, Ruobing; Wang, Qingbo

doi:10.1111/1755-6724.12347

Cited by 63 publications

(26 citation statements)

References 10 publications

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“…Shale reservoir samples in this work (Figure 1) were extracted from the Longmaxi Formation in the Changning-Weiyuan area of Sichuan province, China, which is currently the main commercial exploration and production shale gas target in China (see Figure 2). This formation has been characterised by the high total organic carbon content (TOC), high gas content and is a relatively easily to frack [28][29][30]. Considering that the shale hydration would be strongly affected by the organic matter (kerogen) and inorganic minerals [27,31], a carbon-sulphur analyser and X-ray diffraction Energies 2019, 12, 4225 3 of 20 (XRD) were used to analyse the samples' organic content and mineral compositions.…”

Section: Mineralogymentioning

confidence: 99%

Effect of Shale Anisotropy on Hydration and Its Implications for Water Uptake

Zeng

Jin

et al. 2019

Energies

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Water uptake induced by fluid–rock interaction plays a significant role in the recovery of flowback water during hydraulic fracturing. However, the existing accounts fail to fully acknowledge the significance of shale anisotropy on water uptake typically under in situ reservoir temperature. Thus we investigated the shale-hydration anisotropy using two sets of shale samples from the Longmaxi Formation in Sichuan Basin, China, which are designated to imbibe water parallel and perpendicular to shale bedding planes. All the samples were immersed in distilled water for one to five days at 80 °C or 120 °C. Furthermore, samples’ topographical and elemental variations before and after hydration were quantified using energy-dispersive spectroscopy–field-emission scanning electron microscopy. Our results show that shale anisotropy and imbibition time strongly affect the width of pre-existing micro-fracture in hydrated samples. For imbibition parallel to lamination, the width of pre-existing micro-fracture initially decreases and leads to crack-healing. Subsequently, the crack surfaces slightly collapse and the micro-fracture width is enlarged. In contrast, imbibition perpendicular to lamination does not generate new micro-fracture. Our results imply that during the flowback process of hydraulic fracturing fluid, the shale permeability parallel to bedding planes likely decreases first then increases, thereby promoting the water uptake.

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Section: Mineralogymentioning

confidence: 99%

Effect of Shale Anisotropy on Hydration and Its Implications for Water Uptake

Zeng

Jin

et al. 2019

Energies

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“…The unconventional gas with the most common occurrence of adsorbed gas is associated with adsorption capacity which is controlled primarily by temperature and pressure. The higher the pressure and the lower the temperature are, the higher the adsorption capacity (Wang and Reed 2009;Liu et al 2013;Guo et al 2014). However, under actual geological conditions, the adsorbed gas content in unconventional reservoirs is controlled by the combination of the temperature and pressure changes.…”

Section: Characteristics Of Unconventional Hydrocarbon Accumulationmentioning

confidence: 99%

The concept and the accumulation characteristics of unconventional hydrocarbon resources

Yan

Jiang

et al. 2015

Pet. Sci.

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Unconventional hydrocarbon resources, which are only marginally economically explored and developed by traditional methods and techniques, are different from conventional hydrocarbon resources in their accumulation mechanisms, occurrence states, distribution models, and exploration and development manners. The types of unconventional hydrocarbon are controlled by the evolution of the source rocks and the combinations of different types of unconventional reservoirs. The fundamental distinction between unconventional hydrocarbon resources and conventional hydrocarbon resources is their nonbuoyancy-driven migration. The development of the microto nano-scale pores results in rather high capillary resistance. The accumulation mechanisms of the unconventional and the conventional hydrocarbon resources are also greatly different. In conventional hydrocarbon resources, oil and gas entrapment is controlled by reservoir-forming factors and geological events, which is a dynamic balance process; while for unconventional hydrocarbon resources, the gas content is affected by the temperature and pressure fields, and their preservation is crucial. Unconventional and conventional hydrocarbons are distributed in an orderly manner in subsurface space, having three distribution models of intra-source rock, basin-centered, and source rock interlayer. These results will be of great significance to unconventional hydrocarbon exploration.

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“…Logging and laboratory experiments were the main methods to analyze the physical properties of shale gas reservoirs. Physical property evaluation of shale gas reservoir mainly includes porosity, permeability and saturation of reservoir [5]. Therefore, the purpose of this paper is to investigate the physical and chemical properties of shale from Shahejie group of Jiyang depression for making sure that whether this shale gas reservoir is suitable for producing commercially and give the guides for drilling and exploitation.…”

Section: Introductionmentioning

confidence: 99%

Characteristics of Shale Gas Reservoir in Jiyang Depression and its Significance in Drilling and Exploitation

Liu

Jiang

et al. 2020

IJE

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Physical and geochemical characteristics of shale play conclusive role in confirming operation measures during drilling and stimulation. The properties of shale samples from Jiyang depression were investigated through X-ray diffraction, scanning electron microscope, adsorption isothermal, high pressure mercury intrusion, methylene blue trihydrate, pressure pulse decay, tests of specific water wettability and shale stability index. Correlations, geological and engineering significances of them were discussed. Results show that shale reservoir in Jiyang depression has exploitation value corroborated by good characteristic parameters: 2.86% TOC, 69.9% brittle mineral, 26.14% clay mineral, high permeability of 0.011 × 10-3 μm 2 , large Langmuir volume (5.82 cm 3 /g) and Langmuir specific area (0.91 m 2 /g), effective porosity (3.77%) and thickness (130.66m). Langmuir specific area is the key control on methane adsorption and storage verified by its moderate positive relativity with Langmuir volumes rather than TOC. High illite content (69.29%) may lead to instability of borehole and velocity sensitivity damage. Microfractures provide channels for filtration, invasion and loss of drilling fluid. Large specific water wettability (4.36 × 10-7 g/m 2) and smaller shale stability index (19.99 mm) dispalyed that shale formation were unstable once contacting with fresh water. Countermeasures must be adopted during drilling and fracturing to reduce reservoir damage and complex downhole conditions.

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Geological Features and Reservoiring Mode of Shale Gas Reservoirs in Longmaxi Formation of the Jiaoshiba Area

Cited by 63 publications

References 10 publications

Effect of Shale Anisotropy on Hydration and Its Implications for Water Uptake

Effect of Shale Anisotropy on Hydration and Its Implications for Water Uptake

The concept and the accumulation characteristics of unconventional hydrocarbon resources

Characteristics of Shale Gas Reservoir in Jiyang Depression and its Significance in Drilling and Exploitation

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