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dc.creatorEspinel Diaz, Arnaldo Leopoldo
dc.date.accessioned2012-06-07T22:52:13Z
dc.date.available2012-06-07T22:52:13Z
dc.date.created1998
dc.date.issued1998
dc.identifier.urihttps://hdl.handle.net/1969.1/ETD-TAMU-1998-THESIS-E87
dc.descriptionDue to the character of the original source materials and the nature of batch digitization, quality control issues may be present in this document. Please report any quality issues you encounter to digital@library.tamu.edu, referencing the URI of the item.en
dc.descriptionIncludes bibliographical references: p. 96-101.en
dc.descriptionIssued also on microfiche from Lange Micrographics.en
dc.description.abstractA reservoir management strategy has been developed for a field located in eastern Venezuela. The field contains deep, high pressure, multilayer reservoirs. A thorough formation evaluation was accomplished using the log data, core data, PVT data, geologic data, well completion data and the production data. A reservoir simulation model was built to forecast reservoir performance for a variety of exploitation and well completion strategies. Reserve forecasts have been made using the reservoir model. The methodology applied in this research consists of eight tasks: 1) build a data base with existing data, 2) analyze the log and core data, 3) analyze the pressure and production data, 4) analyze the PVT data, 5) analyze the hydraulic fracture treatments, 6) build the reservoir model, 7) determine the possible reservoir management strategies, and 8) perform economic evaluations for the management strategies. While much of the data for the field studied was supplied by PDVSA, we did not receive all of the data we requested. For example, no pressure buildup data were available. When necessary, we used correlations to determine values for reservoir data that we were not supplied. In this research four formations were studied and characterized, determining porosity and permeability values. Also, fracture treatments were analyzed and a reservoir model was developed. Runs for black oil and volatile oil were performed. The results show that the upper zones are the most prospective areas, but fracture treatments must be performed to reduce the damage on the sand face. Lower formations (Cretaceous) have a lower permeability value, but high OOIP that justify performing fracture treatments and completing this zone. Economics were developed to support this conclusion. Optimum well spacing was calculated showing that 960 acres is the optimum well spacing, but also that 640 acres can be maintained for all the reservoirs and dual completions can be performed, first hydraulic fracturing and completing the Cretaceous formation, and then, completing any upper zone. Reservoir simulation results show that up to 31% of OOIP may be incrementally recovered by hydraulic fracturing the Cretaceous formation and 10 or less from the upper zones.en
dc.format.mediumelectronicen
dc.format.mimetypeapplication/pdf
dc.language.isoen_US
dc.publisherTexas A&M University
dc.rightsThis thesis was part of a retrospective digitization project authorized by the Texas A&M University Libraries in 2008. Copyright remains vested with the author(s). It is the user's responsibility to secure permission from the copyright holder(s) for re-use of the work beyond the provision of Fair Use.en
dc.subjectpetroleum engineering.en
dc.subjectMajor petroleum engineering.en
dc.titleA reservoir management strategy for multilayered reservoirs in eastern Venezuelaen
dc.typeThesisen
thesis.degree.disciplinepetroleum engineeringen
thesis.degree.nameM.S.en
thesis.degree.levelMastersen
dc.type.genrethesisen
dc.type.materialtexten
dc.format.digitalOriginreformatted digitalen


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