Enhanced Oil Recovery from a Carbonate Reservoir During Low Salinity Water Flooding: Spontaneous Imbibition and Core-Flood Methods
Abstract Spontaneous imbibition and core flooding investigations were carried out on limestone core plug samples using different low salinity water (LSW) and smart brines at temperatures of 110 and 50℃, respectively. To demonstrate further the potential of low salinity water injection (LSWI) as an a...
Ausführliche Beschreibung
Gespeichert in:
| Autor*in: |
Shahrabadi, Abbas [verfasserIn] |
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| Format: |
E-Artikel |
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| Sprache: |
Englisch |
| Erschienen: |
2022 |
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| Schlagwörter: |
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| Anmerkung: |
© International Association for Mathematical Geosciences 2022 |
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| Übergeordnetes Werk: |
Enthalten in: Natural resources research - New York, NY [u.a.] : Springer Science + Business Media B.V., 1992, 31(2022), 5 vom: 30. Juni, Seite 2995-3015 |
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| Übergeordnetes Werk: |
volume:31 ; year:2022 ; number:5 ; day:30 ; month:06 ; pages:2995-3015 |
| Links: |
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| DOI / URN: |
10.1007/s11053-022-10092-1 |
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| Katalog-ID: |
SPR048088684 |
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| 100 | 1 | |a Shahrabadi, Abbas |e verfasserin |4 aut | |
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| 520 | |a Abstract Spontaneous imbibition and core flooding investigations were carried out on limestone core plug samples using different low salinity water (LSW) and smart brines at temperatures of 110 and 50℃, respectively. To demonstrate further the potential of low salinity water injection (LSWI) as an agent for enhanced oil recovery (EOR) studies, the interfacial tension (IFT), contact angle (CA), and zeta potential (ZP) were measured. The recovery factor values provided from spontaneous imbibition experiments investigated by formation water (FW), seawater (SW), dilution versions of SW (i.e., 1/2SW, 1/10SW) were 10.07, 15.11, 18.05, and 16.04%, respectively. However, the secondary LSW flooding produced more oil, i.e., a higher recovery factor (37.3, 55, and 61% for FW, SW, and 1/10SW, respectively). The recovery factor obtained from LSW flooding at the tertiary state for SW, 1/2SW, and 1/10SW brines increased up to 11.86, 12.67, and zero, respectively. The main conclusions of the work were as follows. (1) The results of secondary spontaneous imbibition tests showed that LSWI had a significant potential to mobilize the trapped oil. (2) During secondary and tertiary core flooding, the maximum oil recovery (78% of OOIP) was achieved during smart water flooding when the amount of %${\text{SO}}_{4}^{2 - }%$ ion was increased and inactive ions (%${\text{Na}}^{ + }%$ and %${\text{Cl}}^{ - }%$) were eliminated. (3) LSWI and smart water showed significant effects on relative permeability curves, which are indicative of wettability alteration. (4) The main driving mechanism for oil mobilization was found to be wettability alteration, which was supported by the analyses of CA and ZP. | ||
| 650 | 4 | |a Low salinity water flooding |7 (dpeaa)DE-He213 | |
| 650 | 4 | |a smart water |7 (dpeaa)DE-He213 | |
| 650 | 4 | |a spontaneous imbibition |7 (dpeaa)DE-He213 | |
| 650 | 4 | |a core flooding |7 (dpeaa)DE-He213 | |
| 650 | 4 | |a carbonate reservoir |7 (dpeaa)DE-He213 | |
| 650 | 4 | |a wettability alteration |7 (dpeaa)DE-He213 | |
| 700 | 1 | |a Babakhani Dehkordi, Parham |4 aut | |
| 700 | 1 | |a Razavirad, Fatemeh |4 aut | |
| 700 | 1 | |a Noorimotlagh, Reza |4 aut | |
| 700 | 1 | |a Nasiri Zarandi, Masoud |4 aut | |
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10.1007/s11053-022-10092-1 doi (DE-627)SPR048088684 (SPR)s11053-022-10092-1-e DE-627 ger DE-627 rakwb eng Shahrabadi, Abbas verfasserin aut Enhanced Oil Recovery from a Carbonate Reservoir During Low Salinity Water Flooding: Spontaneous Imbibition and Core-Flood Methods 2022 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © International Association for Mathematical Geosciences 2022 Abstract Spontaneous imbibition and core flooding investigations were carried out on limestone core plug samples using different low salinity water (LSW) and smart brines at temperatures of 110 and 50℃, respectively. To demonstrate further the potential of low salinity water injection (LSWI) as an agent for enhanced oil recovery (EOR) studies, the interfacial tension (IFT), contact angle (CA), and zeta potential (ZP) were measured. The recovery factor values provided from spontaneous imbibition experiments investigated by formation water (FW), seawater (SW), dilution versions of SW (i.e., 1/2SW, 1/10SW) were 10.07, 15.11, 18.05, and 16.04%, respectively. However, the secondary LSW flooding produced more oil, i.e., a higher recovery factor (37.3, 55, and 61% for FW, SW, and 1/10SW, respectively). The recovery factor obtained from LSW flooding at the tertiary state for SW, 1/2SW, and 1/10SW brines increased up to 11.86, 12.67, and zero, respectively. The main conclusions of the work were as follows. (1) The results of secondary spontaneous imbibition tests showed that LSWI had a significant potential to mobilize the trapped oil. (2) During secondary and tertiary core flooding, the maximum oil recovery (78% of OOIP) was achieved during smart water flooding when the amount of %${\text{SO}}_{4}^{2 - }%$ ion was increased and inactive ions (%${\text{Na}}^{ + }%$ and %${\text{Cl}}^{ - }%$) were eliminated. (3) LSWI and smart water showed significant effects on relative permeability curves, which are indicative of wettability alteration. (4) The main driving mechanism for oil mobilization was found to be wettability alteration, which was supported by the analyses of CA and ZP. Low salinity water flooding (dpeaa)DE-He213 smart water (dpeaa)DE-He213 spontaneous imbibition (dpeaa)DE-He213 core flooding (dpeaa)DE-He213 carbonate reservoir (dpeaa)DE-He213 wettability alteration (dpeaa)DE-He213 Babakhani Dehkordi, Parham aut Razavirad, Fatemeh aut Noorimotlagh, Reza aut Nasiri Zarandi, Masoud aut Enthalten in Natural resources research New York, NY [u.a.] : Springer Science + Business Media B.V., 1992 31(2022), 5 vom: 30. Juni, Seite 2995-3015 (DE-627)320587622 (DE-600)2018487-6 1573-8981 nnns volume:31 year:2022 number:5 day:30 month:06 pages:2995-3015 https://dx.doi.org/10.1007/s11053-022-10092-1 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_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_152 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_2056 GBV_ILN_2057 GBV_ILN_2059 GBV_ILN_2061 GBV_ILN_2064 GBV_ILN_2065 GBV_ILN_2068 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_2118 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_4126 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_4328 GBV_ILN_4333 GBV_ILN_4334 GBV_ILN_4335 GBV_ILN_4336 GBV_ILN_4338 GBV_ILN_4393 GBV_ILN_4700 AR 31 2022 5 30 06 2995-3015 |
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10.1007/s11053-022-10092-1 doi (DE-627)SPR048088684 (SPR)s11053-022-10092-1-e DE-627 ger DE-627 rakwb eng Shahrabadi, Abbas verfasserin aut Enhanced Oil Recovery from a Carbonate Reservoir During Low Salinity Water Flooding: Spontaneous Imbibition and Core-Flood Methods 2022 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © International Association for Mathematical Geosciences 2022 Abstract Spontaneous imbibition and core flooding investigations were carried out on limestone core plug samples using different low salinity water (LSW) and smart brines at temperatures of 110 and 50℃, respectively. To demonstrate further the potential of low salinity water injection (LSWI) as an agent for enhanced oil recovery (EOR) studies, the interfacial tension (IFT), contact angle (CA), and zeta potential (ZP) were measured. The recovery factor values provided from spontaneous imbibition experiments investigated by formation water (FW), seawater (SW), dilution versions of SW (i.e., 1/2SW, 1/10SW) were 10.07, 15.11, 18.05, and 16.04%, respectively. However, the secondary LSW flooding produced more oil, i.e., a higher recovery factor (37.3, 55, and 61% for FW, SW, and 1/10SW, respectively). The recovery factor obtained from LSW flooding at the tertiary state for SW, 1/2SW, and 1/10SW brines increased up to 11.86, 12.67, and zero, respectively. The main conclusions of the work were as follows. (1) The results of secondary spontaneous imbibition tests showed that LSWI had a significant potential to mobilize the trapped oil. (2) During secondary and tertiary core flooding, the maximum oil recovery (78% of OOIP) was achieved during smart water flooding when the amount of %${\text{SO}}_{4}^{2 - }%$ ion was increased and inactive ions (%${\text{Na}}^{ + }%$ and %${\text{Cl}}^{ - }%$) were eliminated. (3) LSWI and smart water showed significant effects on relative permeability curves, which are indicative of wettability alteration. (4) The main driving mechanism for oil mobilization was found to be wettability alteration, which was supported by the analyses of CA and ZP. Low salinity water flooding (dpeaa)DE-He213 smart water (dpeaa)DE-He213 spontaneous imbibition (dpeaa)DE-He213 core flooding (dpeaa)DE-He213 carbonate reservoir (dpeaa)DE-He213 wettability alteration (dpeaa)DE-He213 Babakhani Dehkordi, Parham aut Razavirad, Fatemeh aut Noorimotlagh, Reza aut Nasiri Zarandi, Masoud aut Enthalten in Natural resources research New York, NY [u.a.] : Springer Science + Business Media B.V., 1992 31(2022), 5 vom: 30. Juni, Seite 2995-3015 (DE-627)320587622 (DE-600)2018487-6 1573-8981 nnns volume:31 year:2022 number:5 day:30 month:06 pages:2995-3015 https://dx.doi.org/10.1007/s11053-022-10092-1 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_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_152 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_2056 GBV_ILN_2057 GBV_ILN_2059 GBV_ILN_2061 GBV_ILN_2064 GBV_ILN_2065 GBV_ILN_2068 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_2118 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_4126 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_4328 GBV_ILN_4333 GBV_ILN_4334 GBV_ILN_4335 GBV_ILN_4336 GBV_ILN_4338 GBV_ILN_4393 GBV_ILN_4700 AR 31 2022 5 30 06 2995-3015 |
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10.1007/s11053-022-10092-1 doi (DE-627)SPR048088684 (SPR)s11053-022-10092-1-e DE-627 ger DE-627 rakwb eng Shahrabadi, Abbas verfasserin aut Enhanced Oil Recovery from a Carbonate Reservoir During Low Salinity Water Flooding: Spontaneous Imbibition and Core-Flood Methods 2022 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © International Association for Mathematical Geosciences 2022 Abstract Spontaneous imbibition and core flooding investigations were carried out on limestone core plug samples using different low salinity water (LSW) and smart brines at temperatures of 110 and 50℃, respectively. To demonstrate further the potential of low salinity water injection (LSWI) as an agent for enhanced oil recovery (EOR) studies, the interfacial tension (IFT), contact angle (CA), and zeta potential (ZP) were measured. The recovery factor values provided from spontaneous imbibition experiments investigated by formation water (FW), seawater (SW), dilution versions of SW (i.e., 1/2SW, 1/10SW) were 10.07, 15.11, 18.05, and 16.04%, respectively. However, the secondary LSW flooding produced more oil, i.e., a higher recovery factor (37.3, 55, and 61% for FW, SW, and 1/10SW, respectively). The recovery factor obtained from LSW flooding at the tertiary state for SW, 1/2SW, and 1/10SW brines increased up to 11.86, 12.67, and zero, respectively. The main conclusions of the work were as follows. (1) The results of secondary spontaneous imbibition tests showed that LSWI had a significant potential to mobilize the trapped oil. (2) During secondary and tertiary core flooding, the maximum oil recovery (78% of OOIP) was achieved during smart water flooding when the amount of %${\text{SO}}_{4}^{2 - }%$ ion was increased and inactive ions (%${\text{Na}}^{ + }%$ and %${\text{Cl}}^{ - }%$) were eliminated. (3) LSWI and smart water showed significant effects on relative permeability curves, which are indicative of wettability alteration. (4) The main driving mechanism for oil mobilization was found to be wettability alteration, which was supported by the analyses of CA and ZP. Low salinity water flooding (dpeaa)DE-He213 smart water (dpeaa)DE-He213 spontaneous imbibition (dpeaa)DE-He213 core flooding (dpeaa)DE-He213 carbonate reservoir (dpeaa)DE-He213 wettability alteration (dpeaa)DE-He213 Babakhani Dehkordi, Parham aut Razavirad, Fatemeh aut Noorimotlagh, Reza aut Nasiri Zarandi, Masoud aut Enthalten in Natural resources research New York, NY [u.a.] : Springer Science + Business Media B.V., 1992 31(2022), 5 vom: 30. Juni, Seite 2995-3015 (DE-627)320587622 (DE-600)2018487-6 1573-8981 nnns volume:31 year:2022 number:5 day:30 month:06 pages:2995-3015 https://dx.doi.org/10.1007/s11053-022-10092-1 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_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_152 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_2056 GBV_ILN_2057 GBV_ILN_2059 GBV_ILN_2061 GBV_ILN_2064 GBV_ILN_2065 GBV_ILN_2068 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_2118 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_4126 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_4328 GBV_ILN_4333 GBV_ILN_4334 GBV_ILN_4335 GBV_ILN_4336 GBV_ILN_4338 GBV_ILN_4393 GBV_ILN_4700 AR 31 2022 5 30 06 2995-3015 |
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10.1007/s11053-022-10092-1 doi (DE-627)SPR048088684 (SPR)s11053-022-10092-1-e DE-627 ger DE-627 rakwb eng Shahrabadi, Abbas verfasserin aut Enhanced Oil Recovery from a Carbonate Reservoir During Low Salinity Water Flooding: Spontaneous Imbibition and Core-Flood Methods 2022 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © International Association for Mathematical Geosciences 2022 Abstract Spontaneous imbibition and core flooding investigations were carried out on limestone core plug samples using different low salinity water (LSW) and smart brines at temperatures of 110 and 50℃, respectively. To demonstrate further the potential of low salinity water injection (LSWI) as an agent for enhanced oil recovery (EOR) studies, the interfacial tension (IFT), contact angle (CA), and zeta potential (ZP) were measured. The recovery factor values provided from spontaneous imbibition experiments investigated by formation water (FW), seawater (SW), dilution versions of SW (i.e., 1/2SW, 1/10SW) were 10.07, 15.11, 18.05, and 16.04%, respectively. However, the secondary LSW flooding produced more oil, i.e., a higher recovery factor (37.3, 55, and 61% for FW, SW, and 1/10SW, respectively). The recovery factor obtained from LSW flooding at the tertiary state for SW, 1/2SW, and 1/10SW brines increased up to 11.86, 12.67, and zero, respectively. The main conclusions of the work were as follows. (1) The results of secondary spontaneous imbibition tests showed that LSWI had a significant potential to mobilize the trapped oil. (2) During secondary and tertiary core flooding, the maximum oil recovery (78% of OOIP) was achieved during smart water flooding when the amount of %${\text{SO}}_{4}^{2 - }%$ ion was increased and inactive ions (%${\text{Na}}^{ + }%$ and %${\text{Cl}}^{ - }%$) were eliminated. (3) LSWI and smart water showed significant effects on relative permeability curves, which are indicative of wettability alteration. (4) The main driving mechanism for oil mobilization was found to be wettability alteration, which was supported by the analyses of CA and ZP. Low salinity water flooding (dpeaa)DE-He213 smart water (dpeaa)DE-He213 spontaneous imbibition (dpeaa)DE-He213 core flooding (dpeaa)DE-He213 carbonate reservoir (dpeaa)DE-He213 wettability alteration (dpeaa)DE-He213 Babakhani Dehkordi, Parham aut Razavirad, Fatemeh aut Noorimotlagh, Reza aut Nasiri Zarandi, Masoud aut Enthalten in Natural resources research New York, NY [u.a.] : Springer Science + Business Media B.V., 1992 31(2022), 5 vom: 30. Juni, Seite 2995-3015 (DE-627)320587622 (DE-600)2018487-6 1573-8981 nnns volume:31 year:2022 number:5 day:30 month:06 pages:2995-3015 https://dx.doi.org/10.1007/s11053-022-10092-1 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_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_152 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_2056 GBV_ILN_2057 GBV_ILN_2059 GBV_ILN_2061 GBV_ILN_2064 GBV_ILN_2065 GBV_ILN_2068 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_2118 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_4126 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_4328 GBV_ILN_4333 GBV_ILN_4334 GBV_ILN_4335 GBV_ILN_4336 GBV_ILN_4338 GBV_ILN_4393 GBV_ILN_4700 AR 31 2022 5 30 06 2995-3015 |
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10.1007/s11053-022-10092-1 doi (DE-627)SPR048088684 (SPR)s11053-022-10092-1-e DE-627 ger DE-627 rakwb eng Shahrabadi, Abbas verfasserin aut Enhanced Oil Recovery from a Carbonate Reservoir During Low Salinity Water Flooding: Spontaneous Imbibition and Core-Flood Methods 2022 Text txt rdacontent Computermedien c rdamedia Online-Ressource cr rdacarrier © International Association for Mathematical Geosciences 2022 Abstract Spontaneous imbibition and core flooding investigations were carried out on limestone core plug samples using different low salinity water (LSW) and smart brines at temperatures of 110 and 50℃, respectively. To demonstrate further the potential of low salinity water injection (LSWI) as an agent for enhanced oil recovery (EOR) studies, the interfacial tension (IFT), contact angle (CA), and zeta potential (ZP) were measured. The recovery factor values provided from spontaneous imbibition experiments investigated by formation water (FW), seawater (SW), dilution versions of SW (i.e., 1/2SW, 1/10SW) were 10.07, 15.11, 18.05, and 16.04%, respectively. However, the secondary LSW flooding produced more oil, i.e., a higher recovery factor (37.3, 55, and 61% for FW, SW, and 1/10SW, respectively). The recovery factor obtained from LSW flooding at the tertiary state for SW, 1/2SW, and 1/10SW brines increased up to 11.86, 12.67, and zero, respectively. The main conclusions of the work were as follows. (1) The results of secondary spontaneous imbibition tests showed that LSWI had a significant potential to mobilize the trapped oil. (2) During secondary and tertiary core flooding, the maximum oil recovery (78% of OOIP) was achieved during smart water flooding when the amount of %${\text{SO}}_{4}^{2 - }%$ ion was increased and inactive ions (%${\text{Na}}^{ + }%$ and %${\text{Cl}}^{ - }%$) were eliminated. (3) LSWI and smart water showed significant effects on relative permeability curves, which are indicative of wettability alteration. (4) The main driving mechanism for oil mobilization was found to be wettability alteration, which was supported by the analyses of CA and ZP. Low salinity water flooding (dpeaa)DE-He213 smart water (dpeaa)DE-He213 spontaneous imbibition (dpeaa)DE-He213 core flooding (dpeaa)DE-He213 carbonate reservoir (dpeaa)DE-He213 wettability alteration (dpeaa)DE-He213 Babakhani Dehkordi, Parham aut Razavirad, Fatemeh aut Noorimotlagh, Reza aut Nasiri Zarandi, Masoud aut Enthalten in Natural resources research New York, NY [u.a.] : Springer Science + Business Media B.V., 1992 31(2022), 5 vom: 30. Juni, Seite 2995-3015 (DE-627)320587622 (DE-600)2018487-6 1573-8981 nnns volume:31 year:2022 number:5 day:30 month:06 pages:2995-3015 https://dx.doi.org/10.1007/s11053-022-10092-1 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_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_152 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_2056 GBV_ILN_2057 GBV_ILN_2059 GBV_ILN_2061 GBV_ILN_2064 GBV_ILN_2065 GBV_ILN_2068 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_2118 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_4126 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_4328 GBV_ILN_4333 GBV_ILN_4334 GBV_ILN_4335 GBV_ILN_4336 GBV_ILN_4338 GBV_ILN_4393 GBV_ILN_4700 AR 31 2022 5 30 06 2995-3015 |
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Enthalten in Natural resources research 31(2022), 5 vom: 30. Juni, Seite 2995-3015 volume:31 year:2022 number:5 day:30 month:06 pages:2995-3015 |
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Enthalten in Natural resources research 31(2022), 5 vom: 30. Juni, Seite 2995-3015 volume:31 year:2022 number:5 day:30 month:06 pages:2995-3015 |
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Shahrabadi, Abbas @@aut@@ Babakhani Dehkordi, Parham @@aut@@ Razavirad, Fatemeh @@aut@@ Noorimotlagh, Reza @@aut@@ Nasiri Zarandi, Masoud @@aut@@ |
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To demonstrate further the potential of low salinity water injection (LSWI) as an agent for enhanced oil recovery (EOR) studies, the interfacial tension (IFT), contact angle (CA), and zeta potential (ZP) were measured. The recovery factor values provided from spontaneous imbibition experiments investigated by formation water (FW), seawater (SW), dilution versions of SW (i.e., 1/2SW, 1/10SW) were 10.07, 15.11, 18.05, and 16.04%, respectively. However, the secondary LSW flooding produced more oil, i.e., a higher recovery factor (37.3, 55, and 61% for FW, SW, and 1/10SW, respectively). The recovery factor obtained from LSW flooding at the tertiary state for SW, 1/2SW, and 1/10SW brines increased up to 11.86, 12.67, and zero, respectively. The main conclusions of the work were as follows. (1) The results of secondary spontaneous imbibition tests showed that LSWI had a significant potential to mobilize the trapped oil. 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|
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Shahrabadi, Abbas |
| spellingShingle |
Shahrabadi, Abbas misc Low salinity water flooding misc smart water misc spontaneous imbibition misc core flooding misc carbonate reservoir misc wettability alteration Enhanced Oil Recovery from a Carbonate Reservoir During Low Salinity Water Flooding: Spontaneous Imbibition and Core-Flood Methods |
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Enhanced Oil Recovery from a Carbonate Reservoir During Low Salinity Water Flooding: Spontaneous Imbibition and Core-Flood Methods Low salinity water flooding (dpeaa)DE-He213 smart water (dpeaa)DE-He213 spontaneous imbibition (dpeaa)DE-He213 core flooding (dpeaa)DE-He213 carbonate reservoir (dpeaa)DE-He213 wettability alteration (dpeaa)DE-He213 |
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misc Low salinity water flooding misc smart water misc spontaneous imbibition misc core flooding misc carbonate reservoir misc wettability alteration |
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Enhanced Oil Recovery from a Carbonate Reservoir During Low Salinity Water Flooding: Spontaneous Imbibition and Core-Flood Methods |
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Enhanced Oil Recovery from a Carbonate Reservoir During Low Salinity Water Flooding: Spontaneous Imbibition and Core-Flood Methods |
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Shahrabadi, Abbas Babakhani Dehkordi, Parham Razavirad, Fatemeh Noorimotlagh, Reza Nasiri Zarandi, Masoud |
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enhanced oil recovery from a carbonate reservoir during low salinity water flooding: spontaneous imbibition and core-flood methods |
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Enhanced Oil Recovery from a Carbonate Reservoir During Low Salinity Water Flooding: Spontaneous Imbibition and Core-Flood Methods |
| abstract |
Abstract Spontaneous imbibition and core flooding investigations were carried out on limestone core plug samples using different low salinity water (LSW) and smart brines at temperatures of 110 and 50℃, respectively. To demonstrate further the potential of low salinity water injection (LSWI) as an agent for enhanced oil recovery (EOR) studies, the interfacial tension (IFT), contact angle (CA), and zeta potential (ZP) were measured. The recovery factor values provided from spontaneous imbibition experiments investigated by formation water (FW), seawater (SW), dilution versions of SW (i.e., 1/2SW, 1/10SW) were 10.07, 15.11, 18.05, and 16.04%, respectively. However, the secondary LSW flooding produced more oil, i.e., a higher recovery factor (37.3, 55, and 61% for FW, SW, and 1/10SW, respectively). The recovery factor obtained from LSW flooding at the tertiary state for SW, 1/2SW, and 1/10SW brines increased up to 11.86, 12.67, and zero, respectively. The main conclusions of the work were as follows. (1) The results of secondary spontaneous imbibition tests showed that LSWI had a significant potential to mobilize the trapped oil. (2) During secondary and tertiary core flooding, the maximum oil recovery (78% of OOIP) was achieved during smart water flooding when the amount of %${\text{SO}}_{4}^{2 - }%$ ion was increased and inactive ions (%${\text{Na}}^{ + }%$ and %${\text{Cl}}^{ - }%$) were eliminated. (3) LSWI and smart water showed significant effects on relative permeability curves, which are indicative of wettability alteration. (4) The main driving mechanism for oil mobilization was found to be wettability alteration, which was supported by the analyses of CA and ZP. © International Association for Mathematical Geosciences 2022 |
| abstractGer |
Abstract Spontaneous imbibition and core flooding investigations were carried out on limestone core plug samples using different low salinity water (LSW) and smart brines at temperatures of 110 and 50℃, respectively. To demonstrate further the potential of low salinity water injection (LSWI) as an agent for enhanced oil recovery (EOR) studies, the interfacial tension (IFT), contact angle (CA), and zeta potential (ZP) were measured. The recovery factor values provided from spontaneous imbibition experiments investigated by formation water (FW), seawater (SW), dilution versions of SW (i.e., 1/2SW, 1/10SW) were 10.07, 15.11, 18.05, and 16.04%, respectively. However, the secondary LSW flooding produced more oil, i.e., a higher recovery factor (37.3, 55, and 61% for FW, SW, and 1/10SW, respectively). The recovery factor obtained from LSW flooding at the tertiary state for SW, 1/2SW, and 1/10SW brines increased up to 11.86, 12.67, and zero, respectively. The main conclusions of the work were as follows. (1) The results of secondary spontaneous imbibition tests showed that LSWI had a significant potential to mobilize the trapped oil. (2) During secondary and tertiary core flooding, the maximum oil recovery (78% of OOIP) was achieved during smart water flooding when the amount of %${\text{SO}}_{4}^{2 - }%$ ion was increased and inactive ions (%${\text{Na}}^{ + }%$ and %${\text{Cl}}^{ - }%$) were eliminated. (3) LSWI and smart water showed significant effects on relative permeability curves, which are indicative of wettability alteration. (4) The main driving mechanism for oil mobilization was found to be wettability alteration, which was supported by the analyses of CA and ZP. © International Association for Mathematical Geosciences 2022 |
| abstract_unstemmed |
Abstract Spontaneous imbibition and core flooding investigations were carried out on limestone core plug samples using different low salinity water (LSW) and smart brines at temperatures of 110 and 50℃, respectively. To demonstrate further the potential of low salinity water injection (LSWI) as an agent for enhanced oil recovery (EOR) studies, the interfacial tension (IFT), contact angle (CA), and zeta potential (ZP) were measured. The recovery factor values provided from spontaneous imbibition experiments investigated by formation water (FW), seawater (SW), dilution versions of SW (i.e., 1/2SW, 1/10SW) were 10.07, 15.11, 18.05, and 16.04%, respectively. However, the secondary LSW flooding produced more oil, i.e., a higher recovery factor (37.3, 55, and 61% for FW, SW, and 1/10SW, respectively). The recovery factor obtained from LSW flooding at the tertiary state for SW, 1/2SW, and 1/10SW brines increased up to 11.86, 12.67, and zero, respectively. The main conclusions of the work were as follows. (1) The results of secondary spontaneous imbibition tests showed that LSWI had a significant potential to mobilize the trapped oil. (2) During secondary and tertiary core flooding, the maximum oil recovery (78% of OOIP) was achieved during smart water flooding when the amount of %${\text{SO}}_{4}^{2 - }%$ ion was increased and inactive ions (%${\text{Na}}^{ + }%$ and %${\text{Cl}}^{ - }%$) were eliminated. (3) LSWI and smart water showed significant effects on relative permeability curves, which are indicative of wettability alteration. (4) The main driving mechanism for oil mobilization was found to be wettability alteration, which was supported by the analyses of CA and ZP. © International Association for Mathematical Geosciences 2022 |
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| title_short |
Enhanced Oil Recovery from a Carbonate Reservoir During Low Salinity Water Flooding: Spontaneous Imbibition and Core-Flood Methods |
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https://dx.doi.org/10.1007/s11053-022-10092-1 |
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Babakhani Dehkordi, Parham Razavirad, Fatemeh Noorimotlagh, Reza Nasiri Zarandi, Masoud |
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10.1007/s11053-022-10092-1 |
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| score |
7.4023542 |