Stress sensitivity of porosity and permeability of Cobourg limestone

Hu, Zhazha; Klaver, Jop; Schmatz, Joyce; Dewanckele, Jan; Littke, Ralf; Krooß, Bernhard M.; Amann-Hildenbrand, Alexandra

doi:10.1016/j.enggeo.2020.105632

Cited by 37 publications

(32 citation statements)

References 56 publications

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“…The porosity equals the ratio of pore to bulk volume. A detailed discussion on the operation of WIP is given in Kuila et al (2014) and Hu et al (2020b).…”

Section: Water Immersion Porosimetry (Wip)mentioning

confidence: 99%

Pore structure and sorption capacity investigations of Ediacaran and Lower Silurian gas shales from the Upper Yangtze platform, China

Gaus

Seemann

et al. 2021

Geomech. Geophys. Geo-energ. Geo-resour.

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The shale gas potential of Ediacaran and Lower Silurian shales from the Upper Yangtze platform is assessed in this study with a focus on the contributions of clay minerals and organic matter to sorption capacity. For this purpose, a multidisciplinary assessment was carried out using petrophysical, mineralogical, petrographic and geochemical methods. In terms of TOC contents (4.2%), brittle mineral contents (68.6%) and maximum gas storage capacities (0.054–0.251 mmol/g) Ediacaran shales from this study show comparable properties to other producing shale gas systems although the thermal maturity is extremely high (VRr = 3.6%). When compared to lower Silurian shales from the same region, it is evident that (1) deeper maximum burial and (2) a lack of silica-associated preservation of the pores resulted in a relatively lower mesopore volume, higher micropore volume fraction and lower overall porosity (Ediacaran shales: 1.4–4.6%; Silurian shales: 6.2–7.4%). Gas production is therefore retarded by poor interconnectivity of the pore system, which was qualitatively demonstrated by comparing experimental gas uptake kinetics. TOC content exhibits a prominent control on sorption capacity and micropore volume for both shales. However, different contributions of clay minerals to sorption capacity were identified. This can partly be attributed to different clay types but is likely also related to burial-induced recrystallisation and different origins of illite. Additionally, it was shown that variations in sorption capacity due to incorrect estimates of clay mineral contribution are in the same range as variations due to differences in thermal maturity. Article highlights Pore structure and gas storage characteristics are evaluated for the first time for Ediacaran Shales from the Upper Yangtze platform Due to a lower free gas storage capacity and diffusivity, the Ediacaran shale can be regarded as a less favorable shale gas prospect when compared to the Silurian shale Clay mineral contribution to sorption capacity is evaluated taking clay mineralogy into consideration Maturity-related changes of organic matter sorption capacity have been discussed on the basis of a compiled data set

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“…The porosity equals the ratio of pore to bulk volume. A detailed discussion on the operation of WIP is given in Kuila et al (2014) and Hu et al (2020b).…”

Section: Water Immersion Porosimetry (Wip)mentioning

confidence: 99%

Pore structure and sorption capacity investigations of Ediacaran and Lower Silurian gas shales from the Upper Yangtze platform, China

Gaus

Seemann

et al. 2021

Geomech. Geophys. Geo-energ. Geo-resour.

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“…Where, Q is flow rate, L/min; A is cross-sectional area, cm 2 ; △h is pressure difference between two ends of the sample, MPa; L is length of the sample, cm; and K is permeability coefficient, L/min. Stress-sensitivity of permeability can be expressed by stress sensitive coefficient (Bustin, 1997;Hu et al, 2020), which is defined as the decreased percentage of permeability within a certain variation of boundary conditions. The stress sensitive coefficient of permeability can be expressed as (Li, 2006):…”

Section: Methodsmentioning

confidence: 99%

Seepage Behavior of Fractures in Paleogene Sandstone Reservoirs in Nanpu Sag, Bohai Bay Basin, Eastern China

Wang

Muhtar

et al. 2021

Front. Earth Sci.

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Natural fractures play an important role in the seepage system of Paleogene sandstone reservoirs at Nanpu Sag. Characteristics and formation mechanisms of natural fractures and stress-sensitivity permeability are comprehensively investigated and their impact on water injection is discussed based on core and log data (FMI and diplog data) as well as stress-sensitivity permeability measurement. Results show that high-angle shear fractures, including NE-SW strike fractures and NW-SE strike fractures, are widely developed in the study area, which were primarily developed during the late Paleogene and late Neogene. The present maximum horizontal principal stress is orientated at N60°–80°E, approximately parallel to the NE-SW fractures, contributing greatly to the seepage system at the early oilfield development stage. Fractures in the study area can be divided into three phases and are characterized by obvious stress-sensitivity permeability, which is closely related to fracture aperture and throat size. Since the fracture occurrence enhances stress sensitivity of permeability, it is necessary to regulate well pattern based on dynamic behaviors of fractured reservoirs at different development stages.

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“…Fan and Liu [33] obtained the permeability hysteresis during the cyclic loading-unloading. Hu et al [34] and Duan et al [35] obtained the permeability hysteresis and stress sensitivity coefficients on the loading path, which were higher than those on the unloading path.…”

Section: Introductionmentioning

confidence: 95%

Permeability Characteristics of Water‐Sand Seepage in Fracture by Experiment

Liu

et al. 2021

Advances in Civil Engineering

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Studies on the seepage characteristics of water-sand cracks are of great significance to reveal the mechanisms of water and sand inrush. Using a self-made water-sand fracture seepage test instrument, a water-sand seepage test was carried out, and the permeability of water and sand in the fracture was determined. The hysteresis characteristics of water-sand flow in the fracture were obtained after the required permeability was attained. The results show that the hysteresis curve changes from type I to type IV with the increase in sand particle size and concentration. The hysteresis parameters are described by the maximum hysteresis Gp ∗ and the hysteresis area S, both of which show an increasing trend with the increase in sand particle size and concentration; however, this increase is not synchronous. The average velocity and turbulent kinetic energy distribution of the water-sand fluid on the fracture cross section are greatly affected by the particle size and concentration of the volume of sand. This study can provide a reference for further study of water inrush from a shallow coal seam. Through simulation, it is found that the particle size has a great influence on the seepage velocity, and the influence near the side wall surface is greater than that in the middle position.

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Stress sensitivity of porosity and permeability of Cobourg limestone

Cited by 37 publications

References 56 publications

Pore structure and sorption capacity investigations of Ediacaran and Lower Silurian gas shales from the Upper Yangtze platform, China

Pore structure and sorption capacity investigations of Ediacaran and Lower Silurian gas shales from the Upper Yangtze platform, China

Seepage Behavior of Fractures in Paleogene Sandstone Reservoirs in Nanpu Sag, Bohai Bay Basin, Eastern China

Permeability Characteristics of Water‐Sand Seepage in Fracture by Experiment

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