{"id":{"repo_id":"tdl","oai_identifier":"oai:tdl-ir.tdl.org:2152/128933"},"canonical_url":"https://search.dev.ndltd.org/etd/tdl/oai:tdl-ir.tdl.org:2152/128933","repository":{"repo_id":"tdl","name":"Texas Digital Library","base_url":"https://tdl-ir.tdl.org/server/oai/request"},"display":{"title":"A streamline model application for the waterflood performance of NZ-OF-HRL carbonate reservoir","abstract":"The NZ-OF-HRL Carbonate reservoir had produced only 3.07 per cent of the oil in place, mainly by internal gas drive, when the pressure had declined from the original pressure of 4,781 psig to 4,009 psig to 8,750 feet. As a result of such rapid change in pressure and due to the fact that energy contribution from the aquifer appears to be negligible, the possibilities of secondary recovery by the injection of water is analyzed in this study. The reservoir performance history was simulated using the streamline model. Three prediction cases were made for different water injection schemes. Each of these predictions were studied in order to design the optimum oil recovery program for future operations. The purpose of drilling new wells would be to increase oil production rate and increase recovery. The purpose of water injection would be to maintain the oil production rate, halt reservoir pressure decline and increase recovery. Our study shows that provided that a reliable source of injection water is established, the optimum water injection program case III should be implemented, A recovery efficiency of 8.4 percent of the original oil-in-place can be expected with this program over a period of twenty years. To achieve the ultimate recovery predicted by the optimum case, drilling of four injection wells is required in addition to converting both wells 30 and 20 to water injection wells","abstract_html":"The NZ-OF-HRL Carbonate reservoir had produced only 3.07 per cent of the oil in place, mainly by internal gas drive, when the pressure had declined from the original pressure of 4,781 psig to 4,009 psig to 8,750 feet. As a result of such rapid change in pressure and due to the fact that energy contribution from the aquifer appears to be negligible, the possibilities of secondary recovery by the injection of water is analyzed in this study. The reservoir performance history was simulated using the streamline model. Three prediction cases were made for different water injection schemes. Each of these predictions were studied in order to design the optimum oil recovery program for future operations. The purpose of drilling new wells would be to increase oil production rate and increase recovery. The purpose of water injection would be to maintain the oil production rate, halt reservoir pressure decline and increase recovery. Our study shows that provided that a reliable source of injection water is established, the optimum water injection program case III should be implemented, A recovery efficiency of 8.4 percent of the original oil-in-place can be expected with this program over a period of twenty years. To achieve the ultimate recovery predicted by the optimum case, drilling of four injection wells is required in addition to converting both wells 30 and 20 to water injection wells","abstract_has_math":false,"creators":["Al-saffar, Abdul-kareem Abdul-azeez"],"institution":null,"degree_name":null,"degree_level":null,"degree_discipline":null,"degree_department":null,"school":null,"contributors":["Caudle, Ben H. (Ben Hall), 1923-"],"advisors":[],"committee_chairs":[],"committee_members":[],"year":1977,"date_issued":"1977","date_published":"1977","updated_at":"2026-07-27T21:19:29Z","subjects":["Oil field flooding","Oil field flooding models","Oil field flooding simulation","Water injection","Waterflood"],"languages":["en"],"rights":["Open","Copyright © is held by the author. Presentation of this material on the Libraries' web site by University Libraries, The University of Texas at Austin was made possible under a limited license grant from the author who has retained all copyrights in the works."],"rights_urls":[],"identifier_entries":[{"key":"dc:identifier","label":"Identifier","values":["https://doi.org/10.26153/tsw/55450"],"render_values":[{"text":"https://doi.org/10.26153/tsw/55450","href":"https://doi.org/10.26153/tsw/55450","code":true}]}]},"links":{"outbound_url":"https://hdl.handle.net/2152/128933","outbound_label":"Handle","outbound_source":"dc:identifier.uri"},"metadata_groups":[{"id":"people","label":"People","entries":[{"key":"dc:contributor","label":"Contributor","values":["Caudle, Ben H. (Ben Hall), 1923-"]},{"key":"dc:creator","label":"Author","values":["Al-saffar, Abdul-kareem Abdul-azeez"]}]},{"id":"academic_context","label":"Academic Context","entries":[{"key":"dc:date.accessioned","label":"Dc Date Accessioned","values":["2024-09-28T22:47:12Z","2026-03-24T18:33:31Z"]},{"key":"dc:date.available","label":"Dc Date Available","values":["2024-09-28T22:47:12Z"]},{"key":"dc:date.issued","label":"Date","values":["1977"]},{"key":"dc:relation","label":"Dc Relation","values":["UT Electronic Theses and Dissertations"]},{"key":"dc:type","label":"Dc Type","values":["Thesis"]}]},{"id":"subjects_keywords","label":"Subjects and Keywords","entries":[{"key":"dc:subject","label":"Dc Subject","values":["Oil field flooding","Oil field flooding models","Oil field flooding simulation","Water injection","Waterflood"]}]},{"id":"language_rights","label":"Language and Rights","entries":[{"key":"dc:language","label":"Dc Language","values":["en"]},{"key":"dc:rights","label":"Dc Rights","values":["Open","Copyright © is held by the author. Presentation of this material on the Libraries' web site by University Libraries, The University of Texas at Austin was made possible under a limited license grant from the author who has retained all copyrights in the works."]}]},{"id":"identifiers","label":"Identifiers","entries":[{"key":"dc:identifier","label":"Identifier","values":["https://hdl.handle.net/2152/128933","https://doi.org/10.26153/tsw/55450"]},{"key":"dc:identifier.uri","label":"Identifier URI","values":["https://hdl.handle.net/2152/128933"]}]},{"id":"additional","label":"Additional Metadata","entries":[{"key":"dc:description.abstract","label":"Abstract","values":["The NZ-OF-HRL Carbonate reservoir had produced only 3.07 per cent of the oil in place, mainly by internal gas drive, when the pressure had declined from the original pressure of 4,781 psig to 4,009 psig to 8,750 feet. As a result of such rapid change in pressure and due to the fact that energy contribution from the aquifer appears to be negligible, the possibilities of secondary recovery by the injection of water is analyzed in this study. The reservoir performance history was simulated using the streamline model. Three prediction cases were made for different water injection schemes. Each of these predictions were studied in order to design the optimum oil recovery program for future operations. The purpose of drilling new wells would be to increase oil production rate and increase recovery. The purpose of water injection would be to maintain the oil production rate, halt reservoir pressure decline and increase recovery. Our study shows that provided that a reliable source of injection water is established, the optimum water injection program case III should be implemented, A recovery efficiency of 8.4 percent of the original oil-in-place can be expected with this program over a period of twenty years. To achieve the ultimate recovery predicted by the optimum case, drilling of four injection wells is required in addition to converting both wells 30 and 20 to water injection wells"]},{"key":"dc:title","label":"Title","values":["A streamline model application for the waterflood performance of NZ-OF-HRL carbonate reservoir"]}]}],"canonical_facts":{"dc:contributor":["Caudle, Ben H. (Ben Hall), 1923-"],"dc:creator":["Al-saffar, Abdul-kareem Abdul-azeez"],"dc:date.accessioned":["2024-09-28T22:47:12Z","2026-03-24T18:33:31Z"],"dc:date.available":["2024-09-28T22:47:12Z"],"dc:date.issued":["1977"],"dc:description.abstract":["The NZ-OF-HRL Carbonate reservoir had produced only 3.07 per cent of the oil in place, mainly by internal gas drive, when the pressure had declined from the original pressure of 4,781 psig to 4,009 psig to 8,750 feet. As a result of such rapid change in pressure and due to the fact that energy contribution from the aquifer appears to be negligible, the possibilities of secondary recovery by the injection of water is analyzed in this study. The reservoir performance history was simulated using the streamline model. Three prediction cases were made for different water injection schemes. Each of these predictions were studied in order to design the optimum oil recovery program for future operations. The purpose of drilling new wells would be to increase oil production rate and increase recovery. The purpose of water injection would be to maintain the oil production rate, halt reservoir pressure decline and increase recovery. Our study shows that provided that a reliable source of injection water is established, the optimum water injection program case III should be implemented, A recovery efficiency of 8.4 percent of the original oil-in-place can be expected with this program over a period of twenty years. To achieve the ultimate recovery predicted by the optimum case, drilling of four injection wells is required in addition to converting both wells 30 and 20 to water injection wells"],"dc:identifier":["https://hdl.handle.net/2152/128933","https://doi.org/10.26153/tsw/55450"],"dc:identifier.uri":["https://hdl.handle.net/2152/128933"],"dc:language":["en"],"dc:relation":["UT Electronic Theses and Dissertations"],"dc:rights":["Open","Copyright © is held by the author. Presentation of this material on the Libraries' web site by University Libraries, The University of Texas at Austin was made possible under a limited license grant from the author who has retained all copyrights in the works."],"dc:subject":["Oil field flooding","Oil field flooding models","Oil field flooding simulation","Water injection","Waterflood"],"dc:title":["A streamline model application for the waterflood performance of NZ-OF-HRL carbonate reservoir"],"dc:type":["Thesis"]},"updated_at":"2026-07-27T21:19:29Z"}