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dc.contributor.authorEnayatpour, Saeid
dc.contributor.authorvan Oort, Eric
dc.contributor.authorPatzek, Tadeusz
dc.date.accessioned2018-05-22T09:46:15Z
dc.date.available2018-05-22T09:46:15Z
dc.date.issued2018-05-17
dc.identifier.citationEnayatpour S, van Oort E, Patzek T (2018) Thermal shale fracturing simulation using the Cohesive Zone Method (CZM). Journal of Natural Gas Science and Engineering. Available: http://dx.doi.org/10.1016/j.jngse.2018.05.014.
dc.identifier.issn1875-5100
dc.identifier.doi10.1016/j.jngse.2018.05.014
dc.identifier.urihttp://hdl.handle.net/10754/627941
dc.description.abstractExtensive research has been conducted over the past two decades to improve hydraulic fracturing methods used for hydrocarbon recovery from tight reservoir rocks such as shales. Our focus in this paper is on thermal fracturing of such tight rocks to enhance hydraulic fracturing efficiency. Thermal fracturing is effective in generating small fractures in the near-wellbore zone - or in the vicinity of natural or induced fractures - that may act as initiation points for larger fractures. Previous analytical and numerical results indicate that thermal fracturing in tight rock significantly enhances rock permeability, thereby enhancing hydrocarbon recovery. Here, we present a more powerful way of simulating the initiation and propagation of thermally induced fractures in tight formations using the Cohesive Zone Method (CZM). The advantages of CZM are: 1) CZM simulation is fast compared to similar models which are based on the spring-mass particle method or Discrete Element Method (DEM); 2) unlike DEM, rock material complexities such as scale-dependent failure behavior can be incorporated in a CZM simulation; 3) CZM is capable of predicting the extent of fracture propagation in rock, which is more difficult to determine in a classic finite element approach. We demonstrate that CZM delivers results for the challenging fracture propagation problem of similar accuracy to the eXtended Finite Element Method (XFEM) while reducing complexity and computational effort. Simulation results for thermal fracturing in the near-wellbore zone show the effect of stress anisotropy in fracture propagation in the direction of the maximum horizontal stress. It is shown that CZM can be used to readily obtain the extent and the pattern of induced thermal fractures.
dc.description.sponsorshipAuthors would like to express their appreciation to the Petroleum and Geosystems Engineering Department of the University of Texas at Austin for computational resources and financial support of this research.
dc.publisherElsevier BV
dc.relation.urlhttps://www.sciencedirect.com/science/article/pii/S1875510018302142
dc.rightsNOTICE: this is the author’s version of a work that was accepted for publication in Journal of Natural Gas Science and Engineering. Changes resulting from the publishing process, such as peer review, editing, corrections, structural formatting, and other quality control mechanisms may not be reflected in this document. Changes may have been made to this work since it was submitted for publication. A definitive version was subsequently published in Journal of Natural Gas Science and Engineering, [, , (2018-05-17)] DOI: 10.1016/j.jngse.2018.05.014 . © 2018. This manuscript version is made available under the CC-BY-NC-ND 4.0 license http://creativecommons.org/licenses/by-nc-nd/4.0/
dc.rights.urihttp://creativecommons.org/licenses/by-nc-nd/4.0/
dc.subjectThermal stimulation
dc.subjectThermal fracturing
dc.subjectCohesive zone method (CZM)
dc.subjectHydraulic fracturing
dc.titleThermal shale fracturing simulation using the Cohesive Zone Method (CZM)
dc.typeArticle
dc.contributor.departmentEarth Science and Engineering Program
dc.contributor.departmentEnergy Resources and Petroleum Engineering
dc.contributor.departmentPhysical Sciences and Engineering (PSE) Division
dc.contributor.departmentUpstream Petroleum Engineering Research Center (UPERC)
dc.identifier.journalJournal of Natural Gas Science and Engineering
dc.eprint.versionPost-print
dc.contributor.institutionPetroleum and Geosystems Engineering, The University of Texas at Austin, TX, USA
kaust.personPatzek, Tadeusz
dc.date.published-online2018-05-17
dc.date.published-print2018-07


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NOTICE: this is the author’s version of a work that was accepted for publication in Journal of Natural Gas Science and Engineering. Changes resulting from the publishing process, such as peer review, editing, corrections, structural formatting, and other quality control mechanisms may not be reflected in this document. Changes may have been made to this work since it was submitted for publication. A definitive version was subsequently published in Journal of Natural Gas Science and Engineering, [, , (2018-05-17)] DOI: 10.1016/j.jngse.2018.05.014 . © 2018. This manuscript version is made available under the CC-BY-NC-ND 4.0 license http://creativecommons.org/licenses/by-nc-nd/4.0/
Except where otherwise noted, this item's license is described as NOTICE: this is the author’s version of a work that was accepted for publication in Journal of Natural Gas Science and Engineering. Changes resulting from the publishing process, such as peer review, editing, corrections, structural formatting, and other quality control mechanisms may not be reflected in this document. Changes may have been made to this work since it was submitted for publication. A definitive version was subsequently published in Journal of Natural Gas Science and Engineering, [, , (2018-05-17)] DOI: 10.1016/j.jngse.2018.05.014 . © 2018. This manuscript version is made available under the CC-BY-NC-ND 4.0 license http://creativecommons.org/licenses/by-nc-nd/4.0/