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dc.contributor.authorSaputra, Wardana
dc.contributor.authorKirati, Wissem
dc.contributor.authorPatzek, Tadeusz
dc.date.accessioned2020-04-23T10:39:24Z
dc.date.available2020-04-22T11:35:48Z
dc.date.available2020-04-23T10:39:24Z
dc.date.issued2020-04-21
dc.date.submitted2020-02-17
dc.identifier.citationSaputra, W., Kirati, W., & Patzek, T. (2020). Physical Scaling of Oil Production Rates and Ultimate Recovery from All Horizontal Wells in the Bakken Shale. Energies, 13(8), 2052. doi:10.3390/en13082052
dc.identifier.issn1996-1073
dc.identifier.doi10.3390/en13082052
dc.identifier.doi10.20944/preprints201912.0334.v1
dc.identifier.urihttp://hdl.handle.net/10754/662610
dc.description.abstractA recent study by the Wall Street Journal reveals that the hydrofractured horizontal wells in shales have been producing less than the industrial forecasts with the empirical hyperbolic decline curve analysis (DCA). As an alternative to DCA, we introduce a simple, fast and accurate method of estimating ultimate recovery in oil shales. We adopt a physics-based scaling approach to analyze oil rates and ultimate recovery from 14,888 active horizontal oil wells in the Bakken shale. To predict the Estimated Ultimate Recovery (EUR), we collapse production records from individual horizontal shale oil wells onto two segments of a master curve: (1) We find that cumulative oil production from 4845 wells is still growing linearly with the square root of time; and (2) 6401 wells are already in exponential decline after approximately seven years on production. In addition, 2363 wells have discontinuous production records, because of refracturing or changes in downhole flowing pressure, and are matched with a linear combination of scaling curves superposed in time. The remaining 1279 new wells with less than 12 months on production have too few production records to allow for robust matches. These wells are scaled with the slopes of other comparable wells in the square-root-of-time flow regime. In the end, we predict that total ultimate recovery from all existing horizontal wells in Bakken will be some 4.5 billion barrels of oil. We also find that wells completed in the Middle Bakken formation, in general, produce more oil than those completed in the Upper Three Forks formation. The newly completed longer wells with larger hydrofractures have higher initial production rates, but they decline faster and have EURs similar to the cheaper old wells. There is little correlation among EUR, lateral length, and the number and size of hydrofractures. Therefore, technology may not help much in boosting production of new wells completed in the poor immature areas along the edges of the Williston Basin. Operators and policymakers may use our findings to optimize the possible futures of the Bakken shale and other plays. More importantly, the petroleum industry may adopt our physics-based method as an alternative to the overly optimistic hyperbolic DCA that yields an ‘illusory picture’ of shale oil resources.
dc.description.sponsorshipThe authors thank the Ali I. Al-Naimi Petroleum Engineering Research Center (ANPERC) at KAUST for supporting this research. We thank the reviewers for their thorough, informative and timely reviews.
dc.description.sponsorshipWardana Saputra (PhD student) was supported by baseline research funding from KAUST to Tad Patzek. Wissem Kirati (Research Engineer) was supported by the Division of Computer, Electrical and Mathematical Science at KAUST.
dc.publisherMDPI AG
dc.relation.urlhttps://www.mdpi.com/1996-1073/13/8/2052
dc.relation.urlhttps://www.mdpi.com/1996-1073/13/8/2052/pdf
dc.rightsThis article is an open access article distributed under the terms and conditions of the Creative Commons Attribution.
dc.rights.urihttps://creativecommons.org/licenses/by/4.0/
dc.titlePhysical Scaling of Oil Production Rates and Ultimate Recovery from All Horizontal Wells in the Bakken Shale
dc.typeArticle
dc.contributor.departmentAli I. Al-Naimi Petroleum Engineering Research Center (ANPERC)
dc.contributor.departmentComputer, Electrical and Mathematical Sciences and Engineering (CEMSE) Division
dc.contributor.departmentEarth Science and Engineering Program
dc.contributor.departmentEnergy Resources & Petroleum Engineering
dc.contributor.departmentEnergy Resources and Petroleum Engineering
dc.contributor.departmentEnergy Resources and Petroleum Engineering Program
dc.contributor.departmentPhysical Science and Engineering (PSE) Division
dc.identifier.journalEnergies
dc.eprint.versionPublisher's Version/PDF
dc.identifier.volume13
dc.identifier.issue8
dc.identifier.pages2052
pubs.publication-statusPublished
kaust.personSaputra, Wardana
kaust.personKirati, Wissem
kaust.personPatzek, Tadeusz
dc.date.accepted2020-03-11
refterms.dateFOA2020-04-22T11:36:29Z
kaust.acknowledged.supportUnitAli I. Al-Naimi Petroleum Engineering Research Center
dc.date.posted2019-12-25


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