RT Journal Article
ID 7313b7161423a271
A1 Ai, Shuang
A1 Cheng, Linsong
A1 Huang, Shijun
A1 Liu, Hongjun
A1 Jia, Zheng
A1 Teng, Bailu
T1 TYPE CURVES FOR PRODUCTION ANALYSIS OF NATURALLY FRACTURED SHALE GAS RESERVOIRS WITH STRESS-SENSITIVE EFFECT
JF Special Topics & Reviews in Porous Media: An International Journal
JO STRPM
YR 2014
FD 2014-06-24
VO 5
IS 2
SP 145
OP 155
K1 shale gas
K1 natural fracture
K1 stress sensitivity
K1 transient linear flow
K1 dual porosity
K1 pseudo-permeability modulus
K1 type curve
AB 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.
PB Begell House
LK https://www.dl.begellhouse.com/journals/3d21681c18f5b5e7,628c144458305103,7313b7161423a271.html