Simulation of nitrogen injection as an Enhanced Recovery Method in a tight natural fracture sandstone reservoir with compositional fluids
The construction of a dual porosity/dual permeability reservoir simulation model requires the estimation of the fracture apertures in every grid cell; generally these apertures are generated stochastically in geo-statistical models which generate a limitation in the consistency between the effective...
- Autores:
-
Herrera Guevara, Carlos Germán
- Tipo de recurso:
- Fecha de publicación:
- 2016
- Institución:
- Universidad Nacional de Colombia
- Repositorio:
- Universidad Nacional de Colombia
- Idioma:
- spa
- OAI Identifier:
- oai:repositorio.unal.edu.co:unal/57083
- Acceso en línea:
- https://repositorio.unal.edu.co/handle/unal/57083
http://bdigital.unal.edu.co/53175/
- Palabra clave:
- 62 Ingeniería y operaciones afines / Engineering
66 Ingeniería química y Tecnologías relacionadas/ Chemical engineering
Gas - Obtención y producción
Inyección de agua en campos petrolíferos
Campos petrolíferos - Métodos de producción
Fluidos composicionales
Campos petrolíferos - Métodos de producción
Pozos petroleros - Fracturamiento hidráulico
Gas manufacture and Works
Oil field flooding
Compositional fluids
Oil fields - Production methods
Oil wells - Hydraulic fracturing
- Rights
- openAccess
- License
- Atribución-NoComercial 4.0 Internacional
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Universidad Nacional de Colombia |
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|
dc.title.spa.fl_str_mv |
Simulation of nitrogen injection as an Enhanced Recovery Method in a tight natural fracture sandstone reservoir with compositional fluids |
title |
Simulation of nitrogen injection as an Enhanced Recovery Method in a tight natural fracture sandstone reservoir with compositional fluids |
spellingShingle |
Simulation of nitrogen injection as an Enhanced Recovery Method in a tight natural fracture sandstone reservoir with compositional fluids 62 Ingeniería y operaciones afines / Engineering 66 Ingeniería química y Tecnologías relacionadas/ Chemical engineering Gas - Obtención y producción Inyección de agua en campos petrolíferos Campos petrolíferos - Métodos de producción Fluidos composicionales Campos petrolíferos - Métodos de producción Pozos petroleros - Fracturamiento hidráulico Gas manufacture and Works Oil field flooding Compositional fluids Oil fields - Production methods Oil wells - Hydraulic fracturing |
title_short |
Simulation of nitrogen injection as an Enhanced Recovery Method in a tight natural fracture sandstone reservoir with compositional fluids |
title_full |
Simulation of nitrogen injection as an Enhanced Recovery Method in a tight natural fracture sandstone reservoir with compositional fluids |
title_fullStr |
Simulation of nitrogen injection as an Enhanced Recovery Method in a tight natural fracture sandstone reservoir with compositional fluids |
title_full_unstemmed |
Simulation of nitrogen injection as an Enhanced Recovery Method in a tight natural fracture sandstone reservoir with compositional fluids |
title_sort |
Simulation of nitrogen injection as an Enhanced Recovery Method in a tight natural fracture sandstone reservoir with compositional fluids |
dc.creator.fl_str_mv |
Herrera Guevara, Carlos Germán |
dc.contributor.author.spa.fl_str_mv |
Herrera Guevara, Carlos Germán |
dc.contributor.spa.fl_str_mv |
Mejía Cárdenas, Juan Manuel |
dc.subject.ddc.spa.fl_str_mv |
62 Ingeniería y operaciones afines / Engineering 66 Ingeniería química y Tecnologías relacionadas/ Chemical engineering |
topic |
62 Ingeniería y operaciones afines / Engineering 66 Ingeniería química y Tecnologías relacionadas/ Chemical engineering Gas - Obtención y producción Inyección de agua en campos petrolíferos Campos petrolíferos - Métodos de producción Fluidos composicionales Campos petrolíferos - Métodos de producción Pozos petroleros - Fracturamiento hidráulico Gas manufacture and Works Oil field flooding Compositional fluids Oil fields - Production methods Oil wells - Hydraulic fracturing |
dc.subject.proposal.spa.fl_str_mv |
Gas - Obtención y producción Inyección de agua en campos petrolíferos Campos petrolíferos - Métodos de producción Fluidos composicionales Campos petrolíferos - Métodos de producción Pozos petroleros - Fracturamiento hidráulico Gas manufacture and Works Oil field flooding Compositional fluids Oil fields - Production methods Oil wells - Hydraulic fracturing |
description |
The construction of a dual porosity/dual permeability reservoir simulation model requires the estimation of the fracture apertures in every grid cell; generally these apertures are generated stochastically in geo-statistical models which generate a limitation in the consistency between the effective fracture permeabilities and fracture porosities measurements and interpretations. This study proposes an effective workflow to overcome the constant aperture assumption generally taken which allows adjusting the apparent aperture for each grid cell by using the matrix permeability, the critically stressed fracture intensity interpretations and the fracture permeability estimated from pressure transient analysis which results in a reliable estimation of shape factors required to estimate the fluid transfer between the matrix and the fracture. Then, using the dual porosity/ dual permeability model it was modeled the nitrogen injection in a gas condensate field. The results shows that: 1) using the Knudsen criteria and capillary pressure measurements it was found that the matrix has a conventional flow even if the permeabilities are very low, 2) the dual porosity/dual permeability model shows a higher oil and gas segregation to the bottom and to the top respectively than the conventional single porosity model due to the high fracture permeabilities, finally 3) it was found that the nitrogen injection shows significant incremental hydrocarbon gas volumes which displacement front can be optimized by adding CO2 into the injection stream. |
publishDate |
2016 |
dc.date.issued.spa.fl_str_mv |
2016-07 |
dc.date.accessioned.spa.fl_str_mv |
2019-07-02T12:24:46Z |
dc.date.available.spa.fl_str_mv |
2019-07-02T12:24:46Z |
dc.type.spa.fl_str_mv |
Trabajo de grado - Maestría |
dc.type.driver.spa.fl_str_mv |
info:eu-repo/semantics/masterThesis |
dc.type.version.spa.fl_str_mv |
info:eu-repo/semantics/acceptedVersion |
dc.type.content.spa.fl_str_mv |
Text |
dc.type.redcol.spa.fl_str_mv |
http://purl.org/redcol/resource_type/TM |
status_str |
acceptedVersion |
dc.identifier.uri.none.fl_str_mv |
https://repositorio.unal.edu.co/handle/unal/57083 |
dc.identifier.eprints.spa.fl_str_mv |
http://bdigital.unal.edu.co/53175/ |
url |
https://repositorio.unal.edu.co/handle/unal/57083 http://bdigital.unal.edu.co/53175/ |
dc.language.iso.spa.fl_str_mv |
spa |
language |
spa |
dc.relation.ispartof.spa.fl_str_mv |
Universidad Nacional de Colombia Sede Medellín Facultad de Minas Escuela de Química y Petróleos Escuela de Química y Petróleos |
dc.relation.references.spa.fl_str_mv |
Herrera Guevara, Carlos Germán (2016) Simulation of nitrogen injection as an Enhanced Recovery Method in a tight natural fracture sandstone reservoir with compositional fluids. Maestría thesis, Universidad Nacional de Colombia - Sede Medellín. |
dc.rights.spa.fl_str_mv |
Derechos reservados - Universidad Nacional de Colombia |
dc.rights.coar.fl_str_mv |
http://purl.org/coar/access_right/c_abf2 |
dc.rights.license.spa.fl_str_mv |
Atribución-NoComercial 4.0 Internacional |
dc.rights.uri.spa.fl_str_mv |
http://creativecommons.org/licenses/by-nc/4.0/ |
dc.rights.accessrights.spa.fl_str_mv |
info:eu-repo/semantics/openAccess |
rights_invalid_str_mv |
Atribución-NoComercial 4.0 Internacional Derechos reservados - Universidad Nacional de Colombia http://creativecommons.org/licenses/by-nc/4.0/ http://purl.org/coar/access_right/c_abf2 |
eu_rights_str_mv |
openAccess |
dc.format.mimetype.spa.fl_str_mv |
application/pdf |
institution |
Universidad Nacional de Colombia |
bitstream.url.fl_str_mv |
https://repositorio.unal.edu.co/bitstream/unal/57083/1/75090447.2016.pdf https://repositorio.unal.edu.co/bitstream/unal/57083/2/75090447.2016.pdf.jpg |
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64c61b454440665a16c26a6277c0262b b25d2166e1dfb69a713bca0175fa21c7 |
bitstream.checksumAlgorithm.fl_str_mv |
MD5 MD5 |
repository.name.fl_str_mv |
Repositorio Institucional Universidad Nacional de Colombia |
repository.mail.fl_str_mv |
repositorio_nal@unal.edu.co |
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1814089815136665600 |
spelling |
Atribución-NoComercial 4.0 InternacionalDerechos reservados - Universidad Nacional de Colombiahttp://creativecommons.org/licenses/by-nc/4.0/info:eu-repo/semantics/openAccesshttp://purl.org/coar/access_right/c_abf2Mejía Cárdenas, Juan ManuelHerrera Guevara, Carlos Germána155c0c2-ca25-47dd-b09c-c061a435e9333002019-07-02T12:24:46Z2019-07-02T12:24:46Z2016-07https://repositorio.unal.edu.co/handle/unal/57083http://bdigital.unal.edu.co/53175/The construction of a dual porosity/dual permeability reservoir simulation model requires the estimation of the fracture apertures in every grid cell; generally these apertures are generated stochastically in geo-statistical models which generate a limitation in the consistency between the effective fracture permeabilities and fracture porosities measurements and interpretations. This study proposes an effective workflow to overcome the constant aperture assumption generally taken which allows adjusting the apparent aperture for each grid cell by using the matrix permeability, the critically stressed fracture intensity interpretations and the fracture permeability estimated from pressure transient analysis which results in a reliable estimation of shape factors required to estimate the fluid transfer between the matrix and the fracture. Then, using the dual porosity/ dual permeability model it was modeled the nitrogen injection in a gas condensate field. The results shows that: 1) using the Knudsen criteria and capillary pressure measurements it was found that the matrix has a conventional flow even if the permeabilities are very low, 2) the dual porosity/dual permeability model shows a higher oil and gas segregation to the bottom and to the top respectively than the conventional single porosity model due to the high fracture permeabilities, finally 3) it was found that the nitrogen injection shows significant incremental hydrocarbon gas volumes which displacement front can be optimized by adding CO2 into the injection stream.Resumen: La construcción de un modelo de simulación de doble porosidad/doble permeabilidad requiere estimar la apertura de las fracturas para cada celda de simulación, generalmente estas aperturas son generadas de forma estocástica con modelos geo-estadísticos el cual presenta limitaciones para lograr consistencia con medidas e interpretaciones entre la permeabilidad efectiva y porosidades de las fracturas. Este estudio propone un flujo de trabajo para eliminar la suposición de aperturas constantes las cuales generalmente son asumidas, el flujo de trabajo permite ajustar las aperturas para cada celda del modelo de simulación por medio del uso de las permeabilidades de matriz, las interpretaciones de las fracturas críticamente estresadas y las permeabilidades de fracturas estimadas con transientes de presión el cual resulta en una estimación del factor de forma requerido para estimar la transferencia de fluidos entre la matriz y la fractura. Utilizando el modelo de doble porosidad/doble permeabilidad se modeló la inyección de nitrógeno en un yacimiento de gas condensado. Los resultados muestran que: 1) utilizando el criterio de knudsen y las medidas de presión capilar se encontró que la matriz presenta flujo convencional aun con permeabilidad tan bajas, 2) el modelo de doble porosidad/doble permeabilidad muestra una mayor segregación del petróleo y el gas al fondo y al tope del yacimiento respectivamente comparado con los modelos convencionales de porosidad simple debido a las altas permeabilidades de las fracturas, finalmente 3) se encontró que la inyección de nitrógeno muestra unos volúmenes incrementales de gas hidrocarburo cuyo frente de desplazamiento puede ser optimizado adicionando CO2 en la corriente de inyección.Maestríaapplication/pdfspaUniversidad Nacional de Colombia Sede Medellín Facultad de Minas Escuela de Química y PetróleosEscuela de Química y PetróleosHerrera Guevara, Carlos Germán (2016) Simulation of nitrogen injection as an Enhanced Recovery Method in a tight natural fracture sandstone reservoir with compositional fluids. Maestría thesis, Universidad Nacional de Colombia - Sede Medellín.62 Ingeniería y operaciones afines / Engineering66 Ingeniería química y Tecnologías relacionadas/ Chemical engineeringGas - Obtención y producciónInyección de agua en campos petrolíferosCampos petrolíferos - Métodos de producciónFluidos composicionalesCampos petrolíferos - Métodos de producciónPozos petroleros - Fracturamiento hidráulicoGas manufacture and WorksOil field floodingCompositional fluidsOil fields - Production methodsOil wells - Hydraulic fracturingSimulation of nitrogen injection as an Enhanced Recovery Method in a tight natural fracture sandstone reservoir with compositional fluidsTrabajo de grado - Maestríainfo:eu-repo/semantics/masterThesisinfo:eu-repo/semantics/acceptedVersionTexthttp://purl.org/redcol/resource_type/TMORIGINAL75090447.2016.pdfTesis de Maestría en Ingeniería - Ingeniería de Petróleosapplication/pdf14948098https://repositorio.unal.edu.co/bitstream/unal/57083/1/75090447.2016.pdf64c61b454440665a16c26a6277c0262bMD51THUMBNAIL75090447.2016.pdf.jpg75090447.2016.pdf.jpgGenerated Thumbnailimage/jpeg4556https://repositorio.unal.edu.co/bitstream/unal/57083/2/75090447.2016.pdf.jpgb25d2166e1dfb69a713bca0175fa21c7MD52unal/57083oai:repositorio.unal.edu.co:unal/570832024-03-26 23:07:44.195Repositorio Institucional Universidad Nacional de Colombiarepositorio_nal@unal.edu.co |