Development of complex layered and fractured reservoir models for reservoir simulation
Abstract The link between the geostatistical modeling of multiscale carbonate heterogeneities and representative simulation flow models remains a challenge because conventional upscaling procedures often disregard the complex dynamic behavior that links the geostatistical static properties, dynamic...
Ausführliche Beschreibung
Gespeichert in:
| Autor*in: |
Correia, Manuel Gomes [verfasserIn] |
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| Format: |
E-Artikel |
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| Sprache: |
Englisch |
| Erschienen: |
2016 |
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| Schlagwörter: |
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| Anmerkung: |
© The Brazilian Society of Mechanical Sciences and Engineering 2016 |
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| Übergeordnetes Werk: |
Enthalten in: Journal of the Brazilian Society of Mechanical Sciences and Engineering - Berlin : Springer, 2003, 39(2016), 1 vom: 25. Juli, Seite 219-233 |
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| Übergeordnetes Werk: |
volume:39 ; year:2016 ; number:1 ; day:25 ; month:07 ; pages:219-233 |
| Links: |
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| DOI / URN: |
10.1007/s40430-016-0606-7 |
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| Katalog-ID: |
SPR036451134 |
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| 100 | 1 | |a Correia, Manuel Gomes |e verfasserin |4 aut | |
| 245 | 1 | 0 | |a Development of complex layered and fractured reservoir models for reservoir simulation |
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| 520 | |a Abstract The link between the geostatistical modeling of multiscale carbonate heterogeneities and representative simulation flow models remains a challenge because conventional upscaling procedures often disregard the complex dynamic behavior that links the geostatistical static properties, dynamic rock/fluid data and reservoir operational conditions. This work proposes a methodology to build robust simulation models for naturally fractured carbonate reservoirs with multiscale geological characterizations. The development of this work follows three main steps: (1) hierarchical upscaling procedure by flow units, (2) integration of flow units into a reservoir-scale simulation model, (3) validation of simulation model. The hierarchical upscaling procedure was applied to three inter-well regions and extrapolated to three flow units. The proposed workflow is applied to a reservoir based on a combination of real and synthetic data from a Brazilian offshore carbonate reservoir. The methodology shows several advantages: it represents static and dynamic behavior from multiscale heterogeneities in reservoir simulation; it minimizes risk in the selection of well position and completion through well characterization of representative static and dynamic data for each flow unit; and, improved selection process for the simulation flow model. The methodology shows that the relative permeability defined in reservoir simulation can be different from the laboratory measured curve because it needs to match the dynamic behavior from the reference solution. This result shows that a proper characterization and upscaling approach are crucial to sufficiently represent geological heterogeneous scenarios in reservoir simulation. The methodology we present here is useful for multidisciplinary areas of expertise as it ensures the appropriate link between the fine scale geomodelling and the coarser scale reservoir simulation, considering the development of complex carbonate reservoirs. | ||
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| 650 | 4 | |a Dual porosity |7 (dpeaa)DE-He213 | |
| 650 | 4 | |a Multiscale heterogeneities |7 (dpeaa)DE-He213 | |
| 650 | 4 | |a Reservoir simulation |7 (dpeaa)DE-He213 | |
| 700 | 1 | |a Maschio, Célio |4 aut | |
| 700 | 1 | |a Schiozer, Denis José |4 aut | |
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10.1007/s40430-016-0606-7 doi (DE-627)SPR036451134 (SPR)s40430-016-0606-7-e DE-627 ger DE-627 rakwb eng Correia, Manuel Gomes verfasserin aut Development of complex layered and fractured reservoir models for reservoir simulation 2016 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © The Brazilian Society of Mechanical Sciences and Engineering 2016 Abstract The link between the geostatistical modeling of multiscale carbonate heterogeneities and representative simulation flow models remains a challenge because conventional upscaling procedures often disregard the complex dynamic behavior that links the geostatistical static properties, dynamic rock/fluid data and reservoir operational conditions. This work proposes a methodology to build robust simulation models for naturally fractured carbonate reservoirs with multiscale geological characterizations. The development of this work follows three main steps: (1) hierarchical upscaling procedure by flow units, (2) integration of flow units into a reservoir-scale simulation model, (3) validation of simulation model. The hierarchical upscaling procedure was applied to three inter-well regions and extrapolated to three flow units. The proposed workflow is applied to a reservoir based on a combination of real and synthetic data from a Brazilian offshore carbonate reservoir. The methodology shows several advantages: it represents static and dynamic behavior from multiscale heterogeneities in reservoir simulation; it minimizes risk in the selection of well position and completion through well characterization of representative static and dynamic data for each flow unit; and, improved selection process for the simulation flow model. The methodology shows that the relative permeability defined in reservoir simulation can be different from the laboratory measured curve because it needs to match the dynamic behavior from the reference solution. This result shows that a proper characterization and upscaling approach are crucial to sufficiently represent geological heterogeneous scenarios in reservoir simulation. The methodology we present here is useful for multidisciplinary areas of expertise as it ensures the appropriate link between the fine scale geomodelling and the coarser scale reservoir simulation, considering the development of complex carbonate reservoirs. Carbonate reservoir (dpeaa)DE-He213 Dual porosity (dpeaa)DE-He213 Multiscale heterogeneities (dpeaa)DE-He213 Reservoir simulation (dpeaa)DE-He213 Maschio, Célio aut Schiozer, Denis José aut Enthalten in Journal of the Brazilian Society of Mechanical Sciences and Engineering Berlin : Springer, 2003 39(2016), 1 vom: 25. Juli, Seite 219-233 (DE-627)387477950 (DE-600)2145288-X 1806-3691 nnns volume:39 year:2016 number:1 day:25 month:07 pages:219-233 https://dx.doi.org/10.1007/s40430-016-0606-7 lizenzpflichtig Volltext GBV_USEFLAG_A SYSFLAG_A GBV_SPRINGER GBV_ILN_11 GBV_ILN_20 GBV_ILN_22 GBV_ILN_23 GBV_ILN_24 GBV_ILN_31 GBV_ILN_32 GBV_ILN_39 GBV_ILN_40 GBV_ILN_60 GBV_ILN_62 GBV_ILN_63 GBV_ILN_65 GBV_ILN_69 GBV_ILN_70 GBV_ILN_73 GBV_ILN_74 GBV_ILN_90 GBV_ILN_95 GBV_ILN_100 GBV_ILN_105 GBV_ILN_110 GBV_ILN_120 GBV_ILN_138 GBV_ILN_150 GBV_ILN_151 GBV_ILN_161 GBV_ILN_170 GBV_ILN_171 GBV_ILN_187 GBV_ILN_213 GBV_ILN_224 GBV_ILN_230 GBV_ILN_250 GBV_ILN_281 GBV_ILN_285 GBV_ILN_293 GBV_ILN_370 GBV_ILN_602 GBV_ILN_636 GBV_ILN_702 GBV_ILN_2001 GBV_ILN_2003 GBV_ILN_2004 GBV_ILN_2005 GBV_ILN_2006 GBV_ILN_2007 GBV_ILN_2008 GBV_ILN_2009 GBV_ILN_2010 GBV_ILN_2011 GBV_ILN_2014 GBV_ILN_2015 GBV_ILN_2020 GBV_ILN_2021 GBV_ILN_2025 GBV_ILN_2026 GBV_ILN_2027 GBV_ILN_2031 GBV_ILN_2034 GBV_ILN_2037 GBV_ILN_2038 GBV_ILN_2039 GBV_ILN_2044 GBV_ILN_2048 GBV_ILN_2049 GBV_ILN_2050 GBV_ILN_2055 GBV_ILN_2057 GBV_ILN_2059 GBV_ILN_2061 GBV_ILN_2064 GBV_ILN_2065 GBV_ILN_2068 GBV_ILN_2070 GBV_ILN_2086 GBV_ILN_2088 GBV_ILN_2093 GBV_ILN_2106 GBV_ILN_2107 GBV_ILN_2108 GBV_ILN_2110 GBV_ILN_2111 GBV_ILN_2112 GBV_ILN_2113 GBV_ILN_2116 GBV_ILN_2118 GBV_ILN_2119 GBV_ILN_2122 GBV_ILN_2129 GBV_ILN_2143 GBV_ILN_2144 GBV_ILN_2147 GBV_ILN_2148 GBV_ILN_2152 GBV_ILN_2153 GBV_ILN_2188 GBV_ILN_2190 GBV_ILN_2232 GBV_ILN_2336 GBV_ILN_2446 GBV_ILN_2470 GBV_ILN_2472 GBV_ILN_2507 GBV_ILN_2522 GBV_ILN_2548 GBV_ILN_4035 GBV_ILN_4037 GBV_ILN_4046 GBV_ILN_4112 GBV_ILN_4125 GBV_ILN_4242 GBV_ILN_4246 GBV_ILN_4249 GBV_ILN_4251 GBV_ILN_4305 GBV_ILN_4306 GBV_ILN_4307 GBV_ILN_4313 GBV_ILN_4322 GBV_ILN_4323 GBV_ILN_4324 GBV_ILN_4325 GBV_ILN_4326 GBV_ILN_4333 GBV_ILN_4334 GBV_ILN_4335 GBV_ILN_4336 GBV_ILN_4338 GBV_ILN_4393 GBV_ILN_4700 AR 39 2016 1 25 07 219-233 |
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10.1007/s40430-016-0606-7 doi (DE-627)SPR036451134 (SPR)s40430-016-0606-7-e DE-627 ger DE-627 rakwb eng Correia, Manuel Gomes verfasserin aut Development of complex layered and fractured reservoir models for reservoir simulation 2016 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © The Brazilian Society of Mechanical Sciences and Engineering 2016 Abstract The link between the geostatistical modeling of multiscale carbonate heterogeneities and representative simulation flow models remains a challenge because conventional upscaling procedures often disregard the complex dynamic behavior that links the geostatistical static properties, dynamic rock/fluid data and reservoir operational conditions. This work proposes a methodology to build robust simulation models for naturally fractured carbonate reservoirs with multiscale geological characterizations. The development of this work follows three main steps: (1) hierarchical upscaling procedure by flow units, (2) integration of flow units into a reservoir-scale simulation model, (3) validation of simulation model. The hierarchical upscaling procedure was applied to three inter-well regions and extrapolated to three flow units. The proposed workflow is applied to a reservoir based on a combination of real and synthetic data from a Brazilian offshore carbonate reservoir. The methodology shows several advantages: it represents static and dynamic behavior from multiscale heterogeneities in reservoir simulation; it minimizes risk in the selection of well position and completion through well characterization of representative static and dynamic data for each flow unit; and, improved selection process for the simulation flow model. The methodology shows that the relative permeability defined in reservoir simulation can be different from the laboratory measured curve because it needs to match the dynamic behavior from the reference solution. This result shows that a proper characterization and upscaling approach are crucial to sufficiently represent geological heterogeneous scenarios in reservoir simulation. The methodology we present here is useful for multidisciplinary areas of expertise as it ensures the appropriate link between the fine scale geomodelling and the coarser scale reservoir simulation, considering the development of complex carbonate reservoirs. Carbonate reservoir (dpeaa)DE-He213 Dual porosity (dpeaa)DE-He213 Multiscale heterogeneities (dpeaa)DE-He213 Reservoir simulation (dpeaa)DE-He213 Maschio, Célio aut Schiozer, Denis José aut Enthalten in Journal of the Brazilian Society of Mechanical Sciences and Engineering Berlin : Springer, 2003 39(2016), 1 vom: 25. Juli, Seite 219-233 (DE-627)387477950 (DE-600)2145288-X 1806-3691 nnns volume:39 year:2016 number:1 day:25 month:07 pages:219-233 https://dx.doi.org/10.1007/s40430-016-0606-7 lizenzpflichtig Volltext GBV_USEFLAG_A SYSFLAG_A GBV_SPRINGER GBV_ILN_11 GBV_ILN_20 GBV_ILN_22 GBV_ILN_23 GBV_ILN_24 GBV_ILN_31 GBV_ILN_32 GBV_ILN_39 GBV_ILN_40 GBV_ILN_60 GBV_ILN_62 GBV_ILN_63 GBV_ILN_65 GBV_ILN_69 GBV_ILN_70 GBV_ILN_73 GBV_ILN_74 GBV_ILN_90 GBV_ILN_95 GBV_ILN_100 GBV_ILN_105 GBV_ILN_110 GBV_ILN_120 GBV_ILN_138 GBV_ILN_150 GBV_ILN_151 GBV_ILN_161 GBV_ILN_170 GBV_ILN_171 GBV_ILN_187 GBV_ILN_213 GBV_ILN_224 GBV_ILN_230 GBV_ILN_250 GBV_ILN_281 GBV_ILN_285 GBV_ILN_293 GBV_ILN_370 GBV_ILN_602 GBV_ILN_636 GBV_ILN_702 GBV_ILN_2001 GBV_ILN_2003 GBV_ILN_2004 GBV_ILN_2005 GBV_ILN_2006 GBV_ILN_2007 GBV_ILN_2008 GBV_ILN_2009 GBV_ILN_2010 GBV_ILN_2011 GBV_ILN_2014 GBV_ILN_2015 GBV_ILN_2020 GBV_ILN_2021 GBV_ILN_2025 GBV_ILN_2026 GBV_ILN_2027 GBV_ILN_2031 GBV_ILN_2034 GBV_ILN_2037 GBV_ILN_2038 GBV_ILN_2039 GBV_ILN_2044 GBV_ILN_2048 GBV_ILN_2049 GBV_ILN_2050 GBV_ILN_2055 GBV_ILN_2057 GBV_ILN_2059 GBV_ILN_2061 GBV_ILN_2064 GBV_ILN_2065 GBV_ILN_2068 GBV_ILN_2070 GBV_ILN_2086 GBV_ILN_2088 GBV_ILN_2093 GBV_ILN_2106 GBV_ILN_2107 GBV_ILN_2108 GBV_ILN_2110 GBV_ILN_2111 GBV_ILN_2112 GBV_ILN_2113 GBV_ILN_2116 GBV_ILN_2118 GBV_ILN_2119 GBV_ILN_2122 GBV_ILN_2129 GBV_ILN_2143 GBV_ILN_2144 GBV_ILN_2147 GBV_ILN_2148 GBV_ILN_2152 GBV_ILN_2153 GBV_ILN_2188 GBV_ILN_2190 GBV_ILN_2232 GBV_ILN_2336 GBV_ILN_2446 GBV_ILN_2470 GBV_ILN_2472 GBV_ILN_2507 GBV_ILN_2522 GBV_ILN_2548 GBV_ILN_4035 GBV_ILN_4037 GBV_ILN_4046 GBV_ILN_4112 GBV_ILN_4125 GBV_ILN_4242 GBV_ILN_4246 GBV_ILN_4249 GBV_ILN_4251 GBV_ILN_4305 GBV_ILN_4306 GBV_ILN_4307 GBV_ILN_4313 GBV_ILN_4322 GBV_ILN_4323 GBV_ILN_4324 GBV_ILN_4325 GBV_ILN_4326 GBV_ILN_4333 GBV_ILN_4334 GBV_ILN_4335 GBV_ILN_4336 GBV_ILN_4338 GBV_ILN_4393 GBV_ILN_4700 AR 39 2016 1 25 07 219-233 |
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10.1007/s40430-016-0606-7 doi (DE-627)SPR036451134 (SPR)s40430-016-0606-7-e DE-627 ger DE-627 rakwb eng Correia, Manuel Gomes verfasserin aut Development of complex layered and fractured reservoir models for reservoir simulation 2016 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © The Brazilian Society of Mechanical Sciences and Engineering 2016 Abstract The link between the geostatistical modeling of multiscale carbonate heterogeneities and representative simulation flow models remains a challenge because conventional upscaling procedures often disregard the complex dynamic behavior that links the geostatistical static properties, dynamic rock/fluid data and reservoir operational conditions. This work proposes a methodology to build robust simulation models for naturally fractured carbonate reservoirs with multiscale geological characterizations. The development of this work follows three main steps: (1) hierarchical upscaling procedure by flow units, (2) integration of flow units into a reservoir-scale simulation model, (3) validation of simulation model. The hierarchical upscaling procedure was applied to three inter-well regions and extrapolated to three flow units. The proposed workflow is applied to a reservoir based on a combination of real and synthetic data from a Brazilian offshore carbonate reservoir. The methodology shows several advantages: it represents static and dynamic behavior from multiscale heterogeneities in reservoir simulation; it minimizes risk in the selection of well position and completion through well characterization of representative static and dynamic data for each flow unit; and, improved selection process for the simulation flow model. The methodology shows that the relative permeability defined in reservoir simulation can be different from the laboratory measured curve because it needs to match the dynamic behavior from the reference solution. This result shows that a proper characterization and upscaling approach are crucial to sufficiently represent geological heterogeneous scenarios in reservoir simulation. The methodology we present here is useful for multidisciplinary areas of expertise as it ensures the appropriate link between the fine scale geomodelling and the coarser scale reservoir simulation, considering the development of complex carbonate reservoirs. Carbonate reservoir (dpeaa)DE-He213 Dual porosity (dpeaa)DE-He213 Multiscale heterogeneities (dpeaa)DE-He213 Reservoir simulation (dpeaa)DE-He213 Maschio, Célio aut Schiozer, Denis José aut Enthalten in Journal of the Brazilian Society of Mechanical Sciences and Engineering Berlin : Springer, 2003 39(2016), 1 vom: 25. Juli, Seite 219-233 (DE-627)387477950 (DE-600)2145288-X 1806-3691 nnns volume:39 year:2016 number:1 day:25 month:07 pages:219-233 https://dx.doi.org/10.1007/s40430-016-0606-7 lizenzpflichtig Volltext GBV_USEFLAG_A SYSFLAG_A GBV_SPRINGER GBV_ILN_11 GBV_ILN_20 GBV_ILN_22 GBV_ILN_23 GBV_ILN_24 GBV_ILN_31 GBV_ILN_32 GBV_ILN_39 GBV_ILN_40 GBV_ILN_60 GBV_ILN_62 GBV_ILN_63 GBV_ILN_65 GBV_ILN_69 GBV_ILN_70 GBV_ILN_73 GBV_ILN_74 GBV_ILN_90 GBV_ILN_95 GBV_ILN_100 GBV_ILN_105 GBV_ILN_110 GBV_ILN_120 GBV_ILN_138 GBV_ILN_150 GBV_ILN_151 GBV_ILN_161 GBV_ILN_170 GBV_ILN_171 GBV_ILN_187 GBV_ILN_213 GBV_ILN_224 GBV_ILN_230 GBV_ILN_250 GBV_ILN_281 GBV_ILN_285 GBV_ILN_293 GBV_ILN_370 GBV_ILN_602 GBV_ILN_636 GBV_ILN_702 GBV_ILN_2001 GBV_ILN_2003 GBV_ILN_2004 GBV_ILN_2005 GBV_ILN_2006 GBV_ILN_2007 GBV_ILN_2008 GBV_ILN_2009 GBV_ILN_2010 GBV_ILN_2011 GBV_ILN_2014 GBV_ILN_2015 GBV_ILN_2020 GBV_ILN_2021 GBV_ILN_2025 GBV_ILN_2026 GBV_ILN_2027 GBV_ILN_2031 GBV_ILN_2034 GBV_ILN_2037 GBV_ILN_2038 GBV_ILN_2039 GBV_ILN_2044 GBV_ILN_2048 GBV_ILN_2049 GBV_ILN_2050 GBV_ILN_2055 GBV_ILN_2057 GBV_ILN_2059 GBV_ILN_2061 GBV_ILN_2064 GBV_ILN_2065 GBV_ILN_2068 GBV_ILN_2070 GBV_ILN_2086 GBV_ILN_2088 GBV_ILN_2093 GBV_ILN_2106 GBV_ILN_2107 GBV_ILN_2108 GBV_ILN_2110 GBV_ILN_2111 GBV_ILN_2112 GBV_ILN_2113 GBV_ILN_2116 GBV_ILN_2118 GBV_ILN_2119 GBV_ILN_2122 GBV_ILN_2129 GBV_ILN_2143 GBV_ILN_2144 GBV_ILN_2147 GBV_ILN_2148 GBV_ILN_2152 GBV_ILN_2153 GBV_ILN_2188 GBV_ILN_2190 GBV_ILN_2232 GBV_ILN_2336 GBV_ILN_2446 GBV_ILN_2470 GBV_ILN_2472 GBV_ILN_2507 GBV_ILN_2522 GBV_ILN_2548 GBV_ILN_4035 GBV_ILN_4037 GBV_ILN_4046 GBV_ILN_4112 GBV_ILN_4125 GBV_ILN_4242 GBV_ILN_4246 GBV_ILN_4249 GBV_ILN_4251 GBV_ILN_4305 GBV_ILN_4306 GBV_ILN_4307 GBV_ILN_4313 GBV_ILN_4322 GBV_ILN_4323 GBV_ILN_4324 GBV_ILN_4325 GBV_ILN_4326 GBV_ILN_4333 GBV_ILN_4334 GBV_ILN_4335 GBV_ILN_4336 GBV_ILN_4338 GBV_ILN_4393 GBV_ILN_4700 AR 39 2016 1 25 07 219-233 |
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10.1007/s40430-016-0606-7 doi (DE-627)SPR036451134 (SPR)s40430-016-0606-7-e DE-627 ger DE-627 rakwb eng Correia, Manuel Gomes verfasserin aut Development of complex layered and fractured reservoir models for reservoir simulation 2016 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © The Brazilian Society of Mechanical Sciences and Engineering 2016 Abstract The link between the geostatistical modeling of multiscale carbonate heterogeneities and representative simulation flow models remains a challenge because conventional upscaling procedures often disregard the complex dynamic behavior that links the geostatistical static properties, dynamic rock/fluid data and reservoir operational conditions. This work proposes a methodology to build robust simulation models for naturally fractured carbonate reservoirs with multiscale geological characterizations. The development of this work follows three main steps: (1) hierarchical upscaling procedure by flow units, (2) integration of flow units into a reservoir-scale simulation model, (3) validation of simulation model. The hierarchical upscaling procedure was applied to three inter-well regions and extrapolated to three flow units. The proposed workflow is applied to a reservoir based on a combination of real and synthetic data from a Brazilian offshore carbonate reservoir. The methodology shows several advantages: it represents static and dynamic behavior from multiscale heterogeneities in reservoir simulation; it minimizes risk in the selection of well position and completion through well characterization of representative static and dynamic data for each flow unit; and, improved selection process for the simulation flow model. The methodology shows that the relative permeability defined in reservoir simulation can be different from the laboratory measured curve because it needs to match the dynamic behavior from the reference solution. This result shows that a proper characterization and upscaling approach are crucial to sufficiently represent geological heterogeneous scenarios in reservoir simulation. The methodology we present here is useful for multidisciplinary areas of expertise as it ensures the appropriate link between the fine scale geomodelling and the coarser scale reservoir simulation, considering the development of complex carbonate reservoirs. Carbonate reservoir (dpeaa)DE-He213 Dual porosity (dpeaa)DE-He213 Multiscale heterogeneities (dpeaa)DE-He213 Reservoir simulation (dpeaa)DE-He213 Maschio, Célio aut Schiozer, Denis José aut Enthalten in Journal of the Brazilian Society of Mechanical Sciences and Engineering Berlin : Springer, 2003 39(2016), 1 vom: 25. Juli, Seite 219-233 (DE-627)387477950 (DE-600)2145288-X 1806-3691 nnns volume:39 year:2016 number:1 day:25 month:07 pages:219-233 https://dx.doi.org/10.1007/s40430-016-0606-7 lizenzpflichtig Volltext GBV_USEFLAG_A SYSFLAG_A GBV_SPRINGER GBV_ILN_11 GBV_ILN_20 GBV_ILN_22 GBV_ILN_23 GBV_ILN_24 GBV_ILN_31 GBV_ILN_32 GBV_ILN_39 GBV_ILN_40 GBV_ILN_60 GBV_ILN_62 GBV_ILN_63 GBV_ILN_65 GBV_ILN_69 GBV_ILN_70 GBV_ILN_73 GBV_ILN_74 GBV_ILN_90 GBV_ILN_95 GBV_ILN_100 GBV_ILN_105 GBV_ILN_110 GBV_ILN_120 GBV_ILN_138 GBV_ILN_150 GBV_ILN_151 GBV_ILN_161 GBV_ILN_170 GBV_ILN_171 GBV_ILN_187 GBV_ILN_213 GBV_ILN_224 GBV_ILN_230 GBV_ILN_250 GBV_ILN_281 GBV_ILN_285 GBV_ILN_293 GBV_ILN_370 GBV_ILN_602 GBV_ILN_636 GBV_ILN_702 GBV_ILN_2001 GBV_ILN_2003 GBV_ILN_2004 GBV_ILN_2005 GBV_ILN_2006 GBV_ILN_2007 GBV_ILN_2008 GBV_ILN_2009 GBV_ILN_2010 GBV_ILN_2011 GBV_ILN_2014 GBV_ILN_2015 GBV_ILN_2020 GBV_ILN_2021 GBV_ILN_2025 GBV_ILN_2026 GBV_ILN_2027 GBV_ILN_2031 GBV_ILN_2034 GBV_ILN_2037 GBV_ILN_2038 GBV_ILN_2039 GBV_ILN_2044 GBV_ILN_2048 GBV_ILN_2049 GBV_ILN_2050 GBV_ILN_2055 GBV_ILN_2057 GBV_ILN_2059 GBV_ILN_2061 GBV_ILN_2064 GBV_ILN_2065 GBV_ILN_2068 GBV_ILN_2070 GBV_ILN_2086 GBV_ILN_2088 GBV_ILN_2093 GBV_ILN_2106 GBV_ILN_2107 GBV_ILN_2108 GBV_ILN_2110 GBV_ILN_2111 GBV_ILN_2112 GBV_ILN_2113 GBV_ILN_2116 GBV_ILN_2118 GBV_ILN_2119 GBV_ILN_2122 GBV_ILN_2129 GBV_ILN_2143 GBV_ILN_2144 GBV_ILN_2147 GBV_ILN_2148 GBV_ILN_2152 GBV_ILN_2153 GBV_ILN_2188 GBV_ILN_2190 GBV_ILN_2232 GBV_ILN_2336 GBV_ILN_2446 GBV_ILN_2470 GBV_ILN_2472 GBV_ILN_2507 GBV_ILN_2522 GBV_ILN_2548 GBV_ILN_4035 GBV_ILN_4037 GBV_ILN_4046 GBV_ILN_4112 GBV_ILN_4125 GBV_ILN_4242 GBV_ILN_4246 GBV_ILN_4249 GBV_ILN_4251 GBV_ILN_4305 GBV_ILN_4306 GBV_ILN_4307 GBV_ILN_4313 GBV_ILN_4322 GBV_ILN_4323 GBV_ILN_4324 GBV_ILN_4325 GBV_ILN_4326 GBV_ILN_4333 GBV_ILN_4334 GBV_ILN_4335 GBV_ILN_4336 GBV_ILN_4338 GBV_ILN_4393 GBV_ILN_4700 AR 39 2016 1 25 07 219-233 |
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10.1007/s40430-016-0606-7 doi (DE-627)SPR036451134 (SPR)s40430-016-0606-7-e DE-627 ger DE-627 rakwb eng Correia, Manuel Gomes verfasserin aut Development of complex layered and fractured reservoir models for reservoir simulation 2016 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © The Brazilian Society of Mechanical Sciences and Engineering 2016 Abstract The link between the geostatistical modeling of multiscale carbonate heterogeneities and representative simulation flow models remains a challenge because conventional upscaling procedures often disregard the complex dynamic behavior that links the geostatistical static properties, dynamic rock/fluid data and reservoir operational conditions. This work proposes a methodology to build robust simulation models for naturally fractured carbonate reservoirs with multiscale geological characterizations. The development of this work follows three main steps: (1) hierarchical upscaling procedure by flow units, (2) integration of flow units into a reservoir-scale simulation model, (3) validation of simulation model. The hierarchical upscaling procedure was applied to three inter-well regions and extrapolated to three flow units. The proposed workflow is applied to a reservoir based on a combination of real and synthetic data from a Brazilian offshore carbonate reservoir. The methodology shows several advantages: it represents static and dynamic behavior from multiscale heterogeneities in reservoir simulation; it minimizes risk in the selection of well position and completion through well characterization of representative static and dynamic data for each flow unit; and, improved selection process for the simulation flow model. The methodology shows that the relative permeability defined in reservoir simulation can be different from the laboratory measured curve because it needs to match the dynamic behavior from the reference solution. This result shows that a proper characterization and upscaling approach are crucial to sufficiently represent geological heterogeneous scenarios in reservoir simulation. The methodology we present here is useful for multidisciplinary areas of expertise as it ensures the appropriate link between the fine scale geomodelling and the coarser scale reservoir simulation, considering the development of complex carbonate reservoirs. Carbonate reservoir (dpeaa)DE-He213 Dual porosity (dpeaa)DE-He213 Multiscale heterogeneities (dpeaa)DE-He213 Reservoir simulation (dpeaa)DE-He213 Maschio, Célio aut Schiozer, Denis José aut Enthalten in Journal of the Brazilian Society of Mechanical Sciences and Engineering Berlin : Springer, 2003 39(2016), 1 vom: 25. Juli, Seite 219-233 (DE-627)387477950 (DE-600)2145288-X 1806-3691 nnns volume:39 year:2016 number:1 day:25 month:07 pages:219-233 https://dx.doi.org/10.1007/s40430-016-0606-7 lizenzpflichtig Volltext GBV_USEFLAG_A SYSFLAG_A GBV_SPRINGER GBV_ILN_11 GBV_ILN_20 GBV_ILN_22 GBV_ILN_23 GBV_ILN_24 GBV_ILN_31 GBV_ILN_32 GBV_ILN_39 GBV_ILN_40 GBV_ILN_60 GBV_ILN_62 GBV_ILN_63 GBV_ILN_65 GBV_ILN_69 GBV_ILN_70 GBV_ILN_73 GBV_ILN_74 GBV_ILN_90 GBV_ILN_95 GBV_ILN_100 GBV_ILN_105 GBV_ILN_110 GBV_ILN_120 GBV_ILN_138 GBV_ILN_150 GBV_ILN_151 GBV_ILN_161 GBV_ILN_170 GBV_ILN_171 GBV_ILN_187 GBV_ILN_213 GBV_ILN_224 GBV_ILN_230 GBV_ILN_250 GBV_ILN_281 GBV_ILN_285 GBV_ILN_293 GBV_ILN_370 GBV_ILN_602 GBV_ILN_636 GBV_ILN_702 GBV_ILN_2001 GBV_ILN_2003 GBV_ILN_2004 GBV_ILN_2005 GBV_ILN_2006 GBV_ILN_2007 GBV_ILN_2008 GBV_ILN_2009 GBV_ILN_2010 GBV_ILN_2011 GBV_ILN_2014 GBV_ILN_2015 GBV_ILN_2020 GBV_ILN_2021 GBV_ILN_2025 GBV_ILN_2026 GBV_ILN_2027 GBV_ILN_2031 GBV_ILN_2034 GBV_ILN_2037 GBV_ILN_2038 GBV_ILN_2039 GBV_ILN_2044 GBV_ILN_2048 GBV_ILN_2049 GBV_ILN_2050 GBV_ILN_2055 GBV_ILN_2057 GBV_ILN_2059 GBV_ILN_2061 GBV_ILN_2064 GBV_ILN_2065 GBV_ILN_2068 GBV_ILN_2070 GBV_ILN_2086 GBV_ILN_2088 GBV_ILN_2093 GBV_ILN_2106 GBV_ILN_2107 GBV_ILN_2108 GBV_ILN_2110 GBV_ILN_2111 GBV_ILN_2112 GBV_ILN_2113 GBV_ILN_2116 GBV_ILN_2118 GBV_ILN_2119 GBV_ILN_2122 GBV_ILN_2129 GBV_ILN_2143 GBV_ILN_2144 GBV_ILN_2147 GBV_ILN_2148 GBV_ILN_2152 GBV_ILN_2153 GBV_ILN_2188 GBV_ILN_2190 GBV_ILN_2232 GBV_ILN_2336 GBV_ILN_2446 GBV_ILN_2470 GBV_ILN_2472 GBV_ILN_2507 GBV_ILN_2522 GBV_ILN_2548 GBV_ILN_4035 GBV_ILN_4037 GBV_ILN_4046 GBV_ILN_4112 GBV_ILN_4125 GBV_ILN_4242 GBV_ILN_4246 GBV_ILN_4249 GBV_ILN_4251 GBV_ILN_4305 GBV_ILN_4306 GBV_ILN_4307 GBV_ILN_4313 GBV_ILN_4322 GBV_ILN_4323 GBV_ILN_4324 GBV_ILN_4325 GBV_ILN_4326 GBV_ILN_4333 GBV_ILN_4334 GBV_ILN_4335 GBV_ILN_4336 GBV_ILN_4338 GBV_ILN_4393 GBV_ILN_4700 AR 39 2016 1 25 07 219-233 |
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This work proposes a methodology to build robust simulation models for naturally fractured carbonate reservoirs with multiscale geological characterizations. The development of this work follows three main steps: (1) hierarchical upscaling procedure by flow units, (2) integration of flow units into a reservoir-scale simulation model, (3) validation of simulation model. The hierarchical upscaling procedure was applied to three inter-well regions and extrapolated to three flow units. The proposed workflow is applied to a reservoir based on a combination of real and synthetic data from a Brazilian offshore carbonate reservoir. The methodology shows several advantages: it represents static and dynamic behavior from multiscale heterogeneities in reservoir simulation; it minimizes risk in the selection of well position and completion through well characterization of representative static and dynamic data for each flow unit; and, improved selection process for the simulation flow model. The methodology shows that the relative permeability defined in reservoir simulation can be different from the laboratory measured curve because it needs to match the dynamic behavior from the reference solution. This result shows that a proper characterization and upscaling approach are crucial to sufficiently represent geological heterogeneous scenarios in reservoir simulation. 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| author |
Correia, Manuel Gomes |
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Correia, Manuel Gomes misc Carbonate reservoir misc Dual porosity misc Multiscale heterogeneities misc Reservoir simulation Development of complex layered and fractured reservoir models for reservoir simulation |
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Development of complex layered and fractured reservoir models for reservoir simulation Carbonate reservoir (dpeaa)DE-He213 Dual porosity (dpeaa)DE-He213 Multiscale heterogeneities (dpeaa)DE-He213 Reservoir simulation (dpeaa)DE-He213 |
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misc Carbonate reservoir misc Dual porosity misc Multiscale heterogeneities misc Reservoir simulation |
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Development of complex layered and fractured reservoir models for reservoir simulation |
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Correia, Manuel Gomes |
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Correia, Manuel Gomes Maschio, Célio Schiozer, Denis José |
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Correia, Manuel Gomes |
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10.1007/s40430-016-0606-7 |
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development of complex layered and fractured reservoir models for reservoir simulation |
| title_auth |
Development of complex layered and fractured reservoir models for reservoir simulation |
| abstract |
Abstract The link between the geostatistical modeling of multiscale carbonate heterogeneities and representative simulation flow models remains a challenge because conventional upscaling procedures often disregard the complex dynamic behavior that links the geostatistical static properties, dynamic rock/fluid data and reservoir operational conditions. This work proposes a methodology to build robust simulation models for naturally fractured carbonate reservoirs with multiscale geological characterizations. The development of this work follows three main steps: (1) hierarchical upscaling procedure by flow units, (2) integration of flow units into a reservoir-scale simulation model, (3) validation of simulation model. The hierarchical upscaling procedure was applied to three inter-well regions and extrapolated to three flow units. The proposed workflow is applied to a reservoir based on a combination of real and synthetic data from a Brazilian offshore carbonate reservoir. The methodology shows several advantages: it represents static and dynamic behavior from multiscale heterogeneities in reservoir simulation; it minimizes risk in the selection of well position and completion through well characterization of representative static and dynamic data for each flow unit; and, improved selection process for the simulation flow model. The methodology shows that the relative permeability defined in reservoir simulation can be different from the laboratory measured curve because it needs to match the dynamic behavior from the reference solution. This result shows that a proper characterization and upscaling approach are crucial to sufficiently represent geological heterogeneous scenarios in reservoir simulation. The methodology we present here is useful for multidisciplinary areas of expertise as it ensures the appropriate link between the fine scale geomodelling and the coarser scale reservoir simulation, considering the development of complex carbonate reservoirs. © The Brazilian Society of Mechanical Sciences and Engineering 2016 |
| abstractGer |
Abstract The link between the geostatistical modeling of multiscale carbonate heterogeneities and representative simulation flow models remains a challenge because conventional upscaling procedures often disregard the complex dynamic behavior that links the geostatistical static properties, dynamic rock/fluid data and reservoir operational conditions. This work proposes a methodology to build robust simulation models for naturally fractured carbonate reservoirs with multiscale geological characterizations. The development of this work follows three main steps: (1) hierarchical upscaling procedure by flow units, (2) integration of flow units into a reservoir-scale simulation model, (3) validation of simulation model. The hierarchical upscaling procedure was applied to three inter-well regions and extrapolated to three flow units. The proposed workflow is applied to a reservoir based on a combination of real and synthetic data from a Brazilian offshore carbonate reservoir. The methodology shows several advantages: it represents static and dynamic behavior from multiscale heterogeneities in reservoir simulation; it minimizes risk in the selection of well position and completion through well characterization of representative static and dynamic data for each flow unit; and, improved selection process for the simulation flow model. The methodology shows that the relative permeability defined in reservoir simulation can be different from the laboratory measured curve because it needs to match the dynamic behavior from the reference solution. This result shows that a proper characterization and upscaling approach are crucial to sufficiently represent geological heterogeneous scenarios in reservoir simulation. The methodology we present here is useful for multidisciplinary areas of expertise as it ensures the appropriate link between the fine scale geomodelling and the coarser scale reservoir simulation, considering the development of complex carbonate reservoirs. © The Brazilian Society of Mechanical Sciences and Engineering 2016 |
| abstract_unstemmed |
Abstract The link between the geostatistical modeling of multiscale carbonate heterogeneities and representative simulation flow models remains a challenge because conventional upscaling procedures often disregard the complex dynamic behavior that links the geostatistical static properties, dynamic rock/fluid data and reservoir operational conditions. This work proposes a methodology to build robust simulation models for naturally fractured carbonate reservoirs with multiscale geological characterizations. The development of this work follows three main steps: (1) hierarchical upscaling procedure by flow units, (2) integration of flow units into a reservoir-scale simulation model, (3) validation of simulation model. The hierarchical upscaling procedure was applied to three inter-well regions and extrapolated to three flow units. The proposed workflow is applied to a reservoir based on a combination of real and synthetic data from a Brazilian offshore carbonate reservoir. The methodology shows several advantages: it represents static and dynamic behavior from multiscale heterogeneities in reservoir simulation; it minimizes risk in the selection of well position and completion through well characterization of representative static and dynamic data for each flow unit; and, improved selection process for the simulation flow model. The methodology shows that the relative permeability defined in reservoir simulation can be different from the laboratory measured curve because it needs to match the dynamic behavior from the reference solution. This result shows that a proper characterization and upscaling approach are crucial to sufficiently represent geological heterogeneous scenarios in reservoir simulation. The methodology we present here is useful for multidisciplinary areas of expertise as it ensures the appropriate link between the fine scale geomodelling and the coarser scale reservoir simulation, considering the development of complex carbonate reservoirs. © The Brazilian Society of Mechanical Sciences and Engineering 2016 |
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Development of complex layered and fractured reservoir models for reservoir simulation |
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https://dx.doi.org/10.1007/s40430-016-0606-7 |
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Maschio, Célio Schiozer, Denis José |
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| doi_str |
10.1007/s40430-016-0606-7 |
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2024-07-03T17:42:00.946Z |
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| score |
7.400337 |