DOI: 10.1306/05181110171
Scopus记录号: 2-s2.0-84857050818
论文题名: Innovative methods for flow-unit and pore-structure analyses in a tight siltstone and shale gas reservoir
作者: Clarkson C.R. ; Jensen J.L. ; Pedersen P.K. ; Freeman M.
刊名: AAPG Bulletin
ISSN: 0149-1794
EISSN: 1558-9524
出版年: 2012
发表日期: 2012
卷: 96, 期: 2 起始页码: 355
结束页码: 374
语种: 英语
Scopus关键词: Adsorption desorption
; Adsorption method
; Bimodal distribution
; Confining pressures
; Core plugs
; In-situ
; Innovative method
; Insitu stress
; Permeability heterogeneity
; Permeability measurements
; Pore shape
; Pore-throat size
; Porosity measurement
; Rapid analysis
; Routine method
; Shale gas
; Siltstones
; Tight gas
; Tight gas reservoirs
; Unimodal
; Adsorption
; Pore size
; Shale
; adsorption
; desorption
; heterogeneity
; hysteresis
; in situ stress
; mercury (element)
; permeability
; pore space
; porosity
; reservoir characterization
; shale
; siltstone
Scopus学科分类: Energy
; Earth and Planetary Sciences
英文摘要: Tight gas reservoirs are notoriously difficult to characterize; routine methods developed for conventional reservoirs are not appropriate for tight gas reservoirs. In this article, we investigate the use of nonroutine methods to characterize permeability heterogeneity and pore structure of a tight gas reservoir for use in flow-unit identification. Profile permeability is used to characterize fine-scale (<1 in. [<2.5 cm]) vertical heterogeneity in a tight gas core; more than 500 measurements were made. Profile permeability, although useful for characterizing heterogeneity, will not provide in-situ estimates of permeability; furthermore, the scale of measurement is much smaller than log scale. Pulse-decay permeability measurements collected on core plugs under confining pressure were used to correct the profile permeability measurements to in-situ stress conditions, and 13-point averages of profile permeability were used to relate to log-derived porosity measurements. Finally, N 2 adsorption, a new method for tight gas was used to estimate the pore-size distribution of several tight gas samples. A unimodal or bimodal distribution was observed for the samples, with the larger peak corresponding to the dominant pore-throat size, as confirmed by independent methods. Furthermore, the adsorption-desorption hysteresis loop shape was used to interpret the dominant pore shape as slot-shaped pores, which is typical of many tight gas reservoirs. The N 2 adsorption method provides rapid analysis and does not suffer from some of the same limitations of Hg injection. In the future, we hope that the N 2 adsorption method may prove useful for flow-unit characterization (based on dominant pore size) of fine-grained (siltstone-shale) tight gas reservoirs. Copyright © 2012. The American Association of Petroleum Geologists. All rights reserved. URL: https://www.scopus.com/inward/record.uri?eid=2-s2.0-84857050818&doi=10.1306%2f05181110171&partnerID=40&md5=f8d998fc9d03add3e081747b227f8486
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资源类型: 期刊论文
标识符: http://119.78.100.158/handle/2HF3EXSE/13364
Appears in Collections: 过去全球变化的重建 影响、适应和脆弱性 科学计划与规划 气候变化与战略 全球变化的国际研究计划 气候减缓与适应 气候变化事实与影响
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Recommended Citation:
Clarkson C.R.,Jensen J.L.,Pedersen P.K.,et al. Innovative methods for flow-unit and pore-structure analyses in a tight siltstone and shale gas reservoir[J]. AAPG Bulletin,2012-01-01,96(2)