DOI: 10.1306/05141312135
Scopus记录号: 2-s2.0-84891637618
论文题名: Organic-rich marcellus shale lithofacies modeling and distribution pattern analysis in the appalachian basin
作者: Wang G. ; Carr T.R.
刊名: AAPG Bulletin
ISSN: 0149-1626
EISSN: 1558-9356
出版年: 2013
发表日期: 2013
卷: 97, 期: 12 起始页码: 2173
结束页码: 2205
语种: 英语
Scopus关键词: Geomechanical properties
; Hydraulic fracture stimulation
; Organic matter content
; Organic matter preservations
; Petrophysical parameters
; Pulsed neutron spectroscopy
; Sequential indicator simulations
; Threedimensional (3-d)
; Biogeochemistry
; Biological materials
; Energy resources
; Geomechanics
; Horizontal wells
; Minerals
; Neural networks
; Organic compounds
; Petroleum reservoirs
; Rocks
; Shale
; Three dimensional
; artificial neural network
; decomposition
; hydraulic fracture
; lithofacies
; mudstone
; natural gas
; organic matter
; reservoir rock
; shale
; shoreline
; simulation
; three-dimensional modeling
; total organic carbon
; Appalachian Basin
; United States
Scopus学科分类: Energy
; Earth and Planetary Sciences
英文摘要: The Marcellus Shale is considered to be the largest unconventional shale-gas resource in the United States. Two critical factors for unconventional shale reservoirs are the response of a unit to hydraulic fracture stimulation and gas content. The fracture attributes reflect the geomechanical properties of the rocks, which are partly related to rock mineralogy. The natural gas content of a shale reservoir rock is strongly linked to organic matter content, measured by total organic carbon (TOC). A mudstone lithofacies is a vertically and laterally continuous zone with similar mineral composition, rock geomechanical properties, and TOC content. Core, log, and seismic data were used to build a three-dimensional (3-D) mudrock lithofacies model from core to wells and, finally, to regional scale. An artificial neural network was used for lithofacies prediction. Eight petrophysical parameters derived from conventional logs were determined as critical inputs. Advanced logs, such as pulsed neutron spectroscopy, with log-determined mineral composition and TOC data were used to improve and confirm the quantitative relationship between conventional logs and lithofacies. Sequential indicator simulation performed well for 3-D modeling of Marcellus Shale lithofacies. The interplay of dilution by terrigenous detritus, organic matter productivity, and organic matter preservation and decomposition affected the distribution of Marcellus Shale lithofacies distribution, which may be attributed to water depth and the distance to shoreline. The trend of normalized average gas production rate from horizontal wells supported our approach to modeling Marcellus Shale lithofacies. The proposed 3-D modeling approach may be helpful for optimizing the design of horizontal well trajectories and hydraulic fracture stimulation strategies. Copyright © 2013. The American Association of Petroleum Geologists. All rights reserved. URL: https://www.scopus.com/inward/record.uri?eid=2-s2.0-84891637618&doi=10.1306%2f05141312135&partnerID=40&md5=c9918471e80d2161dda83766d2cd70fa
Citation statistics:
资源类型: 期刊论文
标识符: http://119.78.100.158/handle/2HF3EXSE/13196
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
There are no files associated with this item.
Recommended Citation:
Wang G.,Carr T.R.. Organic-rich marcellus shale lithofacies modeling and distribution pattern analysis in the appalachian basin[J]. AAPG Bulletin,2013-01-01,97(12)