Analytical modelling of hysteretic constitutive relations governing spontaneous imbibition of fracturing fluid in shale
Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and eva...
Ausführliche Beschreibung
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| Autor*in: |
Ren, Wenxi [verfasserIn] |
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| Format: |
E-Artikel |
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| Sprache: |
Englisch |
| Erschienen: |
2016transfer abstract |
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| Schlagwörter: |
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| Umfang: |
9 |
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| Übergeordnetes Werk: |
Enthalten in: One-step solution-combustion synthesis of complex spinel titanate flake particles with enhanced lithium-storage properties - Li, Xue ELSEVIER, 2015transfer abstract, Amsterdam [u.a.] |
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| Übergeordnetes Werk: |
volume:34 ; year:2016 ; pages:925-933 ; extent:9 |
| Links: |
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| DOI / URN: |
10.1016/j.jngse.2016.07.050 |
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| 245 | 1 | 0 | |a Analytical modelling of hysteretic constitutive relations governing spontaneous imbibition of fracturing fluid in shale |
| 264 | 1 | |c 2016transfer abstract | |
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| 520 | |a Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. | ||
| 520 | |a Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. | ||
| 650 | 7 | |a Analytical model |2 Elsevier | |
| 650 | 7 | |a Spontaneous imbibition |2 Elsevier | |
| 650 | 7 | |a Refracturing |2 Elsevier | |
| 650 | 7 | |a Hysteresis effect |2 Elsevier | |
| 650 | 7 | |a Shale gas |2 Elsevier | |
| 700 | 1 | |a Li, Gensheng |4 oth | |
| 700 | 1 | |a Tian, Shouceng |4 oth | |
| 700 | 1 | |a Sheng, Mao |4 oth | |
| 700 | 1 | |a Geng, Lidong |4 oth | |
| 773 | 0 | 8 | |i Enthalten in |n Elsevier |a Li, Xue ELSEVIER |t One-step solution-combustion synthesis of complex spinel titanate flake particles with enhanced lithium-storage properties |d 2015transfer abstract |g Amsterdam [u.a.] |w (DE-627)ELV013144928 |
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10.1016/j.jngse.2016.07.050 doi GBV00000000000202A.pica (DE-627)ELV024473766 (ELSEVIER)S1875-5100(16)30522-4 DE-627 ger DE-627 rakwb eng 660 660 DE-600 620 VZ 690 VZ 50.92 bkl Ren, Wenxi verfasserin aut Analytical modelling of hysteretic constitutive relations governing spontaneous imbibition of fracturing fluid in shale 2016transfer abstract 9 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. Analytical model Elsevier Spontaneous imbibition Elsevier Refracturing Elsevier Hysteresis effect Elsevier Shale gas Elsevier Li, Gensheng oth Tian, Shouceng oth Sheng, Mao oth Geng, Lidong oth Enthalten in Elsevier Li, Xue ELSEVIER One-step solution-combustion synthesis of complex spinel titanate flake particles with enhanced lithium-storage properties 2015transfer abstract Amsterdam [u.a.] (DE-627)ELV013144928 volume:34 year:2016 pages:925-933 extent:9 https://doi.org/10.1016/j.jngse.2016.07.050 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U 50.92 Meerestechnik VZ AR 34 2016 925-933 9 045F 660 |
| spelling |
10.1016/j.jngse.2016.07.050 doi GBV00000000000202A.pica (DE-627)ELV024473766 (ELSEVIER)S1875-5100(16)30522-4 DE-627 ger DE-627 rakwb eng 660 660 DE-600 620 VZ 690 VZ 50.92 bkl Ren, Wenxi verfasserin aut Analytical modelling of hysteretic constitutive relations governing spontaneous imbibition of fracturing fluid in shale 2016transfer abstract 9 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. Analytical model Elsevier Spontaneous imbibition Elsevier Refracturing Elsevier Hysteresis effect Elsevier Shale gas Elsevier Li, Gensheng oth Tian, Shouceng oth Sheng, Mao oth Geng, Lidong oth Enthalten in Elsevier Li, Xue ELSEVIER One-step solution-combustion synthesis of complex spinel titanate flake particles with enhanced lithium-storage properties 2015transfer abstract Amsterdam [u.a.] (DE-627)ELV013144928 volume:34 year:2016 pages:925-933 extent:9 https://doi.org/10.1016/j.jngse.2016.07.050 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U 50.92 Meerestechnik VZ AR 34 2016 925-933 9 045F 660 |
| allfields_unstemmed |
10.1016/j.jngse.2016.07.050 doi GBV00000000000202A.pica (DE-627)ELV024473766 (ELSEVIER)S1875-5100(16)30522-4 DE-627 ger DE-627 rakwb eng 660 660 DE-600 620 VZ 690 VZ 50.92 bkl Ren, Wenxi verfasserin aut Analytical modelling of hysteretic constitutive relations governing spontaneous imbibition of fracturing fluid in shale 2016transfer abstract 9 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. Analytical model Elsevier Spontaneous imbibition Elsevier Refracturing Elsevier Hysteresis effect Elsevier Shale gas Elsevier Li, Gensheng oth Tian, Shouceng oth Sheng, Mao oth Geng, Lidong oth Enthalten in Elsevier Li, Xue ELSEVIER One-step solution-combustion synthesis of complex spinel titanate flake particles with enhanced lithium-storage properties 2015transfer abstract Amsterdam [u.a.] (DE-627)ELV013144928 volume:34 year:2016 pages:925-933 extent:9 https://doi.org/10.1016/j.jngse.2016.07.050 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U 50.92 Meerestechnik VZ AR 34 2016 925-933 9 045F 660 |
| allfieldsGer |
10.1016/j.jngse.2016.07.050 doi GBV00000000000202A.pica (DE-627)ELV024473766 (ELSEVIER)S1875-5100(16)30522-4 DE-627 ger DE-627 rakwb eng 660 660 DE-600 620 VZ 690 VZ 50.92 bkl Ren, Wenxi verfasserin aut Analytical modelling of hysteretic constitutive relations governing spontaneous imbibition of fracturing fluid in shale 2016transfer abstract 9 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. Analytical model Elsevier Spontaneous imbibition Elsevier Refracturing Elsevier Hysteresis effect Elsevier Shale gas Elsevier Li, Gensheng oth Tian, Shouceng oth Sheng, Mao oth Geng, Lidong oth Enthalten in Elsevier Li, Xue ELSEVIER One-step solution-combustion synthesis of complex spinel titanate flake particles with enhanced lithium-storage properties 2015transfer abstract Amsterdam [u.a.] (DE-627)ELV013144928 volume:34 year:2016 pages:925-933 extent:9 https://doi.org/10.1016/j.jngse.2016.07.050 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U 50.92 Meerestechnik VZ AR 34 2016 925-933 9 045F 660 |
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10.1016/j.jngse.2016.07.050 doi GBV00000000000202A.pica (DE-627)ELV024473766 (ELSEVIER)S1875-5100(16)30522-4 DE-627 ger DE-627 rakwb eng 660 660 DE-600 620 VZ 690 VZ 50.92 bkl Ren, Wenxi verfasserin aut Analytical modelling of hysteretic constitutive relations governing spontaneous imbibition of fracturing fluid in shale 2016transfer abstract 9 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. Analytical model Elsevier Spontaneous imbibition Elsevier Refracturing Elsevier Hysteresis effect Elsevier Shale gas Elsevier Li, Gensheng oth Tian, Shouceng oth Sheng, Mao oth Geng, Lidong oth Enthalten in Elsevier Li, Xue ELSEVIER One-step solution-combustion synthesis of complex spinel titanate flake particles with enhanced lithium-storage properties 2015transfer abstract Amsterdam [u.a.] (DE-627)ELV013144928 volume:34 year:2016 pages:925-933 extent:9 https://doi.org/10.1016/j.jngse.2016.07.050 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U 50.92 Meerestechnik VZ AR 34 2016 925-933 9 045F 660 |
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Enthalten in One-step solution-combustion synthesis of complex spinel titanate flake particles with enhanced lithium-storage properties Amsterdam [u.a.] volume:34 year:2016 pages:925-933 extent:9 |
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One-step solution-combustion synthesis of complex spinel titanate flake particles with enhanced lithium-storage properties |
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In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. 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analytical modelling of hysteretic constitutive relations governing spontaneous imbibition of fracturing fluid in shale |
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Analytical modelling of hysteretic constitutive relations governing spontaneous imbibition of fracturing fluid in shale |
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Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. |
| abstractGer |
Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. |
| abstract_unstemmed |
Understanding spontaneous imbibition of fracturing fluid in shale is critical for hydraulic fracturing design and optimization. In this paper, we present an analytical model for spontaneous imbibition including a hysteretic relative permeability-saturation-capillary pressure (k-S-P) relation and evaluate the relevance of hysteresis effect when modelling fracturing fluid imbibition. In the hysteretic formulations, capillary pressure and relative permeability depend not only on the current saturation but also on the history of saturation in the invaded zone. Herein, we concentrate on fracturing fluid imbibition into shale matrix during shut-in time after refracture treatment, which is driven by the strong capillary forces present in the tight matrix. We demonstrate the importance of accounting for the hysteresis in capillary pressure and relative permeability for predicting the imbibed volume of a fracturing fluid. For a problem that involves drainage and imbibition cycles, a hysteretic k-S-P relation is required to accurately assess the distribution of fluid saturation in the invaded zone. We also demonstrate that although the difference in viscosity between the fracturing fluid and gas is large, the viscosity of the gas cannot be neglected in modelling fracturing fluid imbibition in shale. The results of this investigation are expected to provide a better understanding of fracturing fluid imbibition in shale. |
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