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Daemen, J. J. K.
- Equivalent Permeability Model for Sealing Evaluation of Natural Gas Storage Cavern in Bedded Rock Salt
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PDF Views:142
Authors
Affiliations
1 State Key Laboratory of Geomechanics and Geotechnical Engineering, Institute of Rock and Soil Mechanics, Chinese Academy of Sciences, Wuhan 430071, Hubei, CN
2 College of Pipeline and Civil Engineering, China University of Petroleum, Qingdao 266555, CN
3 Mackay School of Earth Sciences and Engineering, University of Nevada, Reno 89557, Nevada, US
1 State Key Laboratory of Geomechanics and Geotechnical Engineering, Institute of Rock and Soil Mechanics, Chinese Academy of Sciences, Wuhan 430071, Hubei, CN
2 College of Pipeline and Civil Engineering, China University of Petroleum, Qingdao 266555, CN
3 Mackay School of Earth Sciences and Engineering, University of Nevada, Reno 89557, Nevada, US
Source
Current Science, Vol 108, No 4 (2015), Pagination: 723-729Abstract
An equivalent permeability model (EPM) is presented to calculate the equivalent permeability of non-salt layers, which makes the sealing evaluation of bedded salt cavern natural gas storage by numerical simulation easy and sufficient. In the numerical simulations, the effects of non-salt layer property parameters, i.e. horizontal permeability, vertical permeability and dip angle on the sealing of bedded salt cavern natural gas storage can be expressed by a single parameter, the equivalent permeability. We have studied the influence of non-salt dip angle, permeability anisotropy, permeability, buried depth, gas pressure, etc. on the time that it takes for the natural gas to migrate to the ground surface through the non-salt layer formation. The examples show that the EPM is precise and correct, and can meet the actual engineering demands, which includes fewer parameters, and it is implemented easily in numerical simulations. The time needed for natural gas to migrate to the surface is proportional to the increase in anisotropy of permeability and buried depth, but inversely proportional to the increase of non-salt layer dip angle, permeability and internal pressure. The permeability and the dip angle of non-salt layers are the key factors to be considered when analysing the sealing of bedded salt cavern natural gas storage.Keywords
Numerical Simulation, Permeability Anisotropy, Salt Cavern, Sealing.- Experimental Study on The Hydraulic Fracture Propagation In Shale
Abstract Views :257 |
PDF Views:89
Authors
Affiliations
1 School of Energy Science and Engineering, Henan Polytechnic University, Jiaozuo, Henan Province - 454000, CN
2 State Key Laboratory of Geomechanics and Geotechnical Engineering, Institute of Rock and Soil Mechanics, Chinese Academy of Sciences, Wuhan, Hubei - 430071, CN
3 Machay School of Earth Sciences and Engineering, University of Nevada, Reno, NV, US
1 School of Energy Science and Engineering, Henan Polytechnic University, Jiaozuo, Henan Province - 454000, CN
2 State Key Laboratory of Geomechanics and Geotechnical Engineering, Institute of Rock and Soil Mechanics, Chinese Academy of Sciences, Wuhan, Hubei - 430071, CN
3 Machay School of Earth Sciences and Engineering, University of Nevada, Reno, NV, US
Source
Current Science, Vol 115, No 3 (2018), Pagination: 465-475Abstract
To realize the control on geometry of fracture network and improve the individual well production of shale gas reservoirs, hydraulic fracturing simulation tests of shale outcrops for horizontal well were carried out. This was based on an established true triaxial hydraulic fracturing simulation test system, to analyse the propagation and formation of a complex fracture network. The results show that the typical severe fluctuation of pump pressure during extension, is an obvious feature of hydraulic fracturing by Stimulated Reservoir Volume (SRV). Due to the large size and abundant natural fractures in shale specimens, the acoustic emission (AE) energy is weak during propagation of hydraulic fractures. However, fracture propagation can still be effectively determined to some extent, although relatively few AE events are detected. Hydraulic fractures from horizontal well initiate approximately along the maximal in situ stress. But the fractures gradually deviate from the orientation when extending. Branching, re-orientation or penetrating bedding planes and then interconnecting with natural fractures or weak beddings are the main mechanisms of the formation of complicated fracture networks.Keywords
Fracture Propagation, Fracture Network, Hydraulic Fracturing, Shale, Stimulated Reservoir Volume.References
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