Inscrição na biblioteca: Guest
Portal Digital Begell Biblioteca digital da Begell eBooks Diários Referências e Anais Coleções de pesquisa
Special Topics & Reviews in Porous Media: An International Journal
ESCI SJR: 0.259 SNIP: 0.466 CiteScore™: 0.83

ISSN Imprimir: 2151-4798
ISSN On-line: 2151-562X

Special Topics & Reviews in Porous Media: An International Journal

DOI: 10.1615/SpecialTopicsRevPorousMedia.v5.i2.50
pages 145-155

TYPE CURVES FOR PRODUCTION ANALYSIS OF NATURALLY FRACTURED SHALE GAS RESERVOIRS WITH STRESS-SENSITIVE EFFECT

Shuang Ai
Sinopec Research Institute of Petroleum Engineering
Linsong Cheng
Department of Petroleum Engineering, China University of Petroleum–Beijing, 102249 Beijing, PR China
Shijun Huang
MOE Key Laboratory of Petroleum Engineering, China University of Petroleum, Beijing 102249, China
Hongjun Liu
MOE Key Laboratory of Petroleum Engineering, China University of Petroleum, Beijing 102249, China
Zheng Jia
MOE Key Laboratory of Petroleum Engineering, China University of Petroleum, Beijing 102249, China
Bailu Teng
MOE Key Laboratory of Petroleum Engineering, China University of Petroleum, Beijing 102249, China

RESUMO

Shale permeability is generally very low, from 10−6 to 10−3 mD, making it extremely difficult for intra-formational gas to flow on a large scale. To address this problem, horizontal wells and multi-stage fracturing are employed to develop low-permeability shale gas reservoirs. During multi-stage hydraulic fracturing, natural fractures reopen and form pathways for gas to flow, the process of which is called stimulated reservoir volume (SRV). Transient linear flow is identified as the dominant flow regime in SRV, which has been verified by theoretical studies and production performance. As production progresses, the natural fracture permeability stimulated during multi-stage fracturing declines along with the reservoir pressure. Previous research and production flow models have not considered the permeability-decreasing effect of stimulated natural fractures. For this study, a transient linear dual-porosity model was designed to investigate the performance of multi-fractured horizontal shale gas wells relative to the stress-sensitive permeability of natural fractures. Type curves were analyzed using Laplace transformation and numeric inverse transformation. Our results show that significant error occurs if the stress sensitivity of natural fractures is neglected when using traditional type curve analysis for production parameters of fractured horizontal wells in shale reservoirs.


Articles with similar content:

MODELING THE NONLINEAR FLOW FOR A MULTIPLE-FRACTURED HORIZONTAL WELL WITH MULTIPLE FINITE-CONDUCTIVITY FRACTURES IN TRIPLE MEDIA CARBONATE RESERVOIR
Journal of Porous Media, Vol.21, 2018, issue 12
Yong Wang, Xin Ma, Chen Zhang, Tao Chen
TRANSIENT PRESSURE BEHAVIOR OF A FRACTURED VERTICAL WELL WITH A FINITE-CONDUCTIVITY FRACTURE IN TRIPLE MEDIA CARBONATE RESERVOIR
Journal of Porous Media, Vol.20, 2017, issue 8
Yong Wang, Xiangyi Yi
ESTABLISHMENT OF PRODUCTIVITY MODEL AND ORTHOGONAL TEST DESIGN FOR ANALYSIS OF DOMINATING FACTORS IN FRACTURED SHALE GAS RESERVOIRS
Journal of Porous Media, Vol.22, 2019, issue 6
Ya Deng, Guangdong Wang, Leng Tian, Cong Xiao, Yanchen Wang
TRANSIENT PRODUCTION DECLINE BEHAVIOR ANALYSIS FOR A MULTI-FRACTURED HORIZONTAL WELL WITH DISCRETE FRACTURE NETWORKS IN SHALE GAS RESERVOIRS
Journal of Porous Media, Vol.22, 2019, issue 3
Mingqiang Wei, Yonggang Duan, Mingzhe Dong, Morteza Dejam, Quantang Fang
FRACTURING FLUID LEAKOFF BEHAVIOR IN NATURAL FRACTURES: EFFECTS OF FLUID RHEOLOGY, NATURAL FRACTURE DEFORMABILITY, AND HYDRAULIC FRACTURE PROPAGATION
Journal of Porous Media, Vol.20, 2017, issue 2
Yuxuan Liu, Jianchun Guo, Zhangxin Chen