Publication de 4 numéros par an
ISSN Imprimer: 2151-4798
ISSN En ligne: 2151-562X
Indexed in
TYPE CURVES FOR PRODUCTION ANALYSIS OF NATURALLY FRACTURED SHALE GAS RESERVOIRS WITH STRESS-SENSITIVE EFFECT
RÉSUMÉ
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.
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Geng Lidong, Li Gensheng, Wang Minsheng, Li Ying, Tian Shouceng, Pang Wei, Lyu Zehao, A fractal production prediction model for shale gas reservoirs, Journal of Natural Gas Science and Engineering, 55, 2018. Crossref