Use of a Variable Shape Distribution (VSD) Model to Populate Reservoir Properties in Tight Fractured Reservoirs for Numerical 3D Modeling

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atmire.migration.oldid1861
dc.contributor.advisorAguilera, Roberto
dc.contributor.authorRamirez Vargas, John Freddy
dc.date.accessioned2014-01-28T23:01:26Z
dc.date.available2016-02-11T21:13:15Z
dc.date.issued2014-01-28
dc.date.submitted2014en
dc.description.abstractHydrodynamic plots of tight formations in the Deep Basin of the Western Canada Sedimentary Basin (WCSB) indicate the lack of a water leg and the presence of water on top of gas; quite unconventional. Furthermore, experience indicates that in many instances properties such as matrix and fracture density in these tight formations cannot be modeled using conventional statistical distributions. Widely used approaches such as normal, geometric and fractal distributions do not reproduce accurately the behaviour of such properties in many cases. Thus it could be said that the unconventional fluids distribution meets the unconventional rocks distribution in unconventional formations. These occurrences have led to the development of the research presented in this work. Original contributions are as follows: 1) Reservoir simulation covering over 1.5 million years that corroborates the presence of a block of water on top of gas in the tight gas Nikanassin formation of the WCSB. 2) Implementation of a new methodology to populate matrix and fracture density properties in reservoir simulation with the use of a Variable Shape Distribution (VSD) model. The question is if it is reasonable to think that gas can be trapped for hundreds of years and more by an updip water block. A reservoir simulation model has been created as indicated in item 1 above in order to answer this question. The water seal is shown to be the result of very low permeability and high capillary pressures, properties that are generally found in tight gas formations. The model is defined by a geometry that mimics the geologic interpretation of the Nikanassin Basin Center Gas Accumulation (BCGA) in the Western Canada Sedimentary Basin (WCSB) and rock properties that provide a good representation of the real behavior of the reservoir in the Deep Basin of Alberta. Reservoir simulation has been used historically to model in the order of 10 to 40 years of production. But to our knowledge this is the first reservoir simulation that goes beyond 1.5 million years. The results lead to the conclusion that updip water blocks provide good seals in the Deep Basin. The new methodology mentioned above in item 2 introduces an extension of the VSD approach for reservoir simulation purposes. In the original methodology when matching input information in the VSD equation, each data point is assigned an integer according to its ranking (Nt) in the overall sample population. If these integers are used in a normal score transformation for reservoir simulation, the hard data (for example permeability) will not be honoured. As a result, in order to honour the hard data, the integers have been replaced with real numbers found by calculating the values that produce the exact data points when input into the VSD equation. Since this equation has an exponential form it cannot be solved directly for Nt and it is necessary to perform an iterative process to find the exact values. The new methodology is demonstrated with data from the WCSB tight gas Nikanassin Group and Cadomin formation. The result is a good comparison between wells with the best cumulative gas production and areas with the largest fracture density in Township 65 Range 09, located in the Rocky Mountains in Alberta. The results lead to recommendations to drill and multi-stage hydraulically fracture horizontal wells in specific areas of such Township. It is concluded that the VSD is a valuable tool that has significant potential for applications in conventional, low and ultra-low permeability formations and for evaluating distribution of rock properties at the micro and nano-scale. In the case of reservoir simulation the VSD can be extended to generate more rigorous static models.en_US
dc.description.embargoterms2 yearsen_US
dc.identifier.citationRamirez Vargas, J. F. (2014). Use of a Variable Shape Distribution (VSD) Model to Populate Reservoir Properties in Tight Fractured Reservoirs for Numerical 3D Modeling (Master's thesis, University of Calgary, Calgary, Canada). Retrieved from https://prism.ucalgary.ca. doi:10.11575/PRISM/28605en_US
dc.identifier.doihttp://dx.doi.org/10.11575/PRISM/28605
dc.identifier.urihttp://hdl.handle.net/11023/1306
dc.language.isoeng
dc.publisher.facultyGraduate Studies
dc.publisher.institutionUniversity of Calgaryen
dc.publisher.placeCalgaryen
dc.rightsUniversity of Calgary graduate students retain copyright ownership and moral rights for their thesis. You may use this material in any way that is permitted by the Copyright Act or through licensing that has been assigned to the document. For uses that are not allowable under copyright legislation or licensing, you are required to seek permission.
dc.subjectEngineering--Petroleum
dc.subject.classificationVariable Shape Distributionen_US
dc.subject.classificationReservoir Engineeringen_US
dc.subject.classificationFormation Evaluationen_US
dc.subject.classificationReservoir Modelingen_US
dc.subject.classificationPetrophysical Modelingen_US
dc.subject.classificationGeostatisticsen_US
dc.subject.classificationTight Gasen_US
dc.subject.classificationNaturally Fractured Reservoirsen_US
dc.subject.classificationNikanassinen_US
dc.subject.classificationWestern Canada Sedimentary Basinen_US
dc.subject.classificationDeep Basinen_US
dc.titleUse of a Variable Shape Distribution (VSD) Model to Populate Reservoir Properties in Tight Fractured Reservoirs for Numerical 3D Modeling
dc.typemaster thesis
thesis.degree.disciplineChemical and Petroleum Engineering
thesis.degree.grantorUniversity of Calgary
thesis.degree.nameMaster of Science (MSc)
ucalgary.item.requestcopytrue
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