Mechanical and Elastic Characterization of Shale Gas Play in Upper Indus Basin, Pakistan

Khalid, Perveiz; Ehsan, Muhammad Irfan; Metwaly, Mohamed; Khurram, Shahzada

doi:10.1007/s13369-020-05275-y

Cited by 6 publications

(2 citation statements)

References 31 publications

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“…where φ D = porosity from density log, ρ matrix = density of matrix, ρ log = density from log tool, ρ fluid = density of the reservoir fluid, ϕ N = porosity from neutron log, ϕ T = total porosity, ϕ e = effective porosity, ΔT = sonic transit time, and ϕ s = porosity derived from sonic log. The natural radioactive material in the formation is measured from the GR log, which is taken as a lithological Frontiers in Earth Science frontiersin.org log (Khalid et al, 2021). The volume of shale (V sh ) was calculated using the relationships proposed by Clavier (1977), Stieber (1970) and Larionov (1969), based on the GR log and GR index (I GR ).…”

Section: Methodsmentioning

confidence: 99%

Reservoir quality and facies modeling of the early Eocene carbonate stratigraphic unit of the Middle Indus Basin, Pakistan

et al. 2022

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The early Eocene carbonate reservoir, Sui Main Limestone (SML), is the largest gas reservoir in Pakistan. In the Qadirpur area, more than 30 wells have been drilled, some of which have been declared dry or abandoned due to poor reservoir characteristics or facies variation. The aim of this work is to re-evaluate the reservoir characteristics and facies identification of Sui Main Limestone by using petrophysical analysis and rock physics modeling in the Qadirpur field in the Middle Indus Basin of Pakistan. The reservoir characterization of carbonate rocks is difficult because of their complex pore networking. The well data on five exploratory wells drilled in this gas field are used. The log-derived porosity varies in a very large range of 2%–36%, with an average of 14%–34%. The average porosity of the clean carbonate intervals is 10%–14% and thus has the capacity to accumulate hydrocarbon. The high porosity value indicates the presence of micro-fractures in Sui Main Limestone. These micro-fractures and secondary pores are well interconnected and allow the pore fluids to communicate. The secondary porosity is mainly due to the presence of vuggs and fractures in Sui Main Limestone. The volume of shale varies from 11%–38% in the wells. The net pay zones have hydrocarbon saturation in the range of 40%–70%, which is mainly gas. Using wireline log response, the formation is divided into three facies: limestone, shale, and shaly limestone. This comprehensive work may help improve the prediction of the reservoir quality in heterogeneous carbonate reservoirs and optimize field development.

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Section: Methodsmentioning

confidence: 99%

Reservoir quality and facies modeling of the early Eocene carbonate stratigraphic unit of the Middle Indus Basin, Pakistan

et al. 2022

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“…It then breaks through the interface and continues to expand in the original direction. Zou et al [12] and Zhou et al [13] studied the influence of bedding on fracture morphology in shale reservoirs. They considered the medium vertical stress difference a favorable condition for the formation of a complex fracture network.…”

Section: Introductionmentioning

confidence: 99%

Influence of Horizontal Multi-Bedding on Hydraulic Fracture Propagation in Shale Reservoirs

Jiang,

Wei,

et al. 2023

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Artificial fractures can easily occur and propagate in shale reservoir bedding. Their height restricts the volume of fracturing modification. A physical simulation of true triaxial hydraulic fracturing was used to analyze the characteristics of fracture morphology and the fracturing curve, as well as explore the influence of horizontal multi-bedding on the hydraulic fracture propagation of shale reservoirs. The results showed that a weaker bedding strength increased bedding fracture activation and reduced the fracture height. A higher bedding density increased the fracture complexity and reduced the main fracture height. A high injection flow can easily cause morphologically complex multi-bedding fractures. A higher injected fracturing-fluid viscosity increased the layer-penetration ability of the main hydraulic fracture when it expanded and reduced the opening degree of the bedding plane. This study provides technical support for the hydraulic fracturing design of shale reservoirs.

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Application of instantaneous spectral decomposition-based porosity simulations for imaging shallow-marine stratigraphic traps of Lower-Eocene carbonates sequences of Indus Basin, Onshore Pakistan

Naseer

2023

J Earth Syst Sci

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Mechanical and Elastic Characterization of Shale Gas Play in Upper Indus Basin, Pakistan

Cited by 6 publications

References 31 publications

Reservoir quality and facies modeling of the early Eocene carbonate stratigraphic unit of the Middle Indus Basin, Pakistan

Reservoir quality and facies modeling of the early Eocene carbonate stratigraphic unit of the Middle Indus Basin, Pakistan

Influence of Horizontal Multi-Bedding on Hydraulic Fracture Propagation in Shale Reservoirs

Application of instantaneous spectral decomposition-based porosity simulations for imaging shallow-marine stratigraphic traps of Lower-Eocene carbonates sequences of Indus Basin, Onshore Pakistan

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