An approach to waterflood optimization: case study of the reservoir X
Abstract Over the years, waterflooding has been the most widely used secondary oil recovery method after the exhaustion of the primary depletion energy of the reservoir. Waterflooding schemes have to be planned such that at every point of the operation, net income from oil recovery exceeds operating...
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| Format: | Article |
| Language: | English |
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SpringerOpen
2017-07-01
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| Series: | Journal of Petroleum Exploration and Production Technology |
| Subjects: | |
| Online Access: | http://link.springer.com/article/10.1007/s13202-017-0368-5 |
| _version_ | 1797998193952161792 |
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| author | Precious Ogbeiwi Yetunde Aladeitan Dickson Udebhulu |
| author_facet | Precious Ogbeiwi Yetunde Aladeitan Dickson Udebhulu |
| author_sort | Precious Ogbeiwi |
| collection | DOAJ |
| description | Abstract Over the years, waterflooding has been the most widely used secondary oil recovery method after the exhaustion of the primary depletion energy of the reservoir. Waterflooding schemes have to be planned such that at every point of the operation, net income from oil recovery exceeds operating expenditure of which produced water disposal cost is paramount. Hence, engineers are regularly plagued with challenges such as optimal completions zones for injectors and producers, optimal flood pattern to adopt and number/type of producers and injectors to use in waterflood field development so as to improve oil recovery, but reduce water production. The aim of this study is to optimize waterflooding from a case study model using reservoir simulation techniques. A simple optimization methodology involving the analysis of the effects of zones of production and injection, pattern of waterflood selected and number/type of producers and injectors on cumulative recovery from a waterflooded reservoir was used. Results revealed that (1) pressure maintenance/increment is more effective when there is water injection into more zones of the reservoir, (2) for waterflood operations involving the use of vertical injectors, higher water production was observed because water is expected to flow more conveniently in the upward direction due to gravity rather than laterally and (3) with horizontal injectors, higher cumulative production was achieved especially for cases where water is injected into the same zones from which oil is produced. |
| first_indexed | 2024-04-11T10:44:48Z |
| format | Article |
| id | doaj.art-afdc6d17e60a4d6e9d69fc97290ff58a |
| institution | Directory Open Access Journal |
| issn | 2190-0558 2190-0566 |
| language | English |
| last_indexed | 2024-04-11T10:44:48Z |
| publishDate | 2017-07-01 |
| publisher | SpringerOpen |
| record_format | Article |
| series | Journal of Petroleum Exploration and Production Technology |
| spelling | doaj.art-afdc6d17e60a4d6e9d69fc97290ff58a2022-12-22T04:29:06ZengSpringerOpenJournal of Petroleum Exploration and Production Technology2190-05582190-05662017-07-018127128910.1007/s13202-017-0368-5An approach to waterflood optimization: case study of the reservoir XPrecious Ogbeiwi0Yetunde Aladeitan1Dickson Udebhulu2Department of Petroleum Engineering, African University of Science and TechnologyDepartment of Petroleum Engineering, African University of Science and TechnologyDepartment of Petroleum Engineering, African University of Science and TechnologyAbstract Over the years, waterflooding has been the most widely used secondary oil recovery method after the exhaustion of the primary depletion energy of the reservoir. Waterflooding schemes have to be planned such that at every point of the operation, net income from oil recovery exceeds operating expenditure of which produced water disposal cost is paramount. Hence, engineers are regularly plagued with challenges such as optimal completions zones for injectors and producers, optimal flood pattern to adopt and number/type of producers and injectors to use in waterflood field development so as to improve oil recovery, but reduce water production. The aim of this study is to optimize waterflooding from a case study model using reservoir simulation techniques. A simple optimization methodology involving the analysis of the effects of zones of production and injection, pattern of waterflood selected and number/type of producers and injectors on cumulative recovery from a waterflooded reservoir was used. Results revealed that (1) pressure maintenance/increment is more effective when there is water injection into more zones of the reservoir, (2) for waterflood operations involving the use of vertical injectors, higher water production was observed because water is expected to flow more conveniently in the upward direction due to gravity rather than laterally and (3) with horizontal injectors, higher cumulative production was achieved especially for cases where water is injected into the same zones from which oil is produced.http://link.springer.com/article/10.1007/s13202-017-0368-5WaterfloodingOptimizationReservoirSimulationOil recoveryPerformance |
| spellingShingle | Precious Ogbeiwi Yetunde Aladeitan Dickson Udebhulu An approach to waterflood optimization: case study of the reservoir X Journal of Petroleum Exploration and Production Technology Waterflooding Optimization Reservoir Simulation Oil recovery Performance |
| title | An approach to waterflood optimization: case study of the reservoir X |
| title_full | An approach to waterflood optimization: case study of the reservoir X |
| title_fullStr | An approach to waterflood optimization: case study of the reservoir X |
| title_full_unstemmed | An approach to waterflood optimization: case study of the reservoir X |
| title_short | An approach to waterflood optimization: case study of the reservoir X |
| title_sort | approach to waterflood optimization case study of the reservoir x |
| topic | Waterflooding Optimization Reservoir Simulation Oil recovery Performance |
| url | http://link.springer.com/article/10.1007/s13202-017-0368-5 |
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