Capturing the effects of secondary fractures on production data using flow regime equations and specialised plots: An uncertainty analysis approach
Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosi...
Ausführliche Beschreibung
Gespeichert in:
| Autor*in: |
Ezulike, Obinna Daniel [verfasserIn] |
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| Format: |
E-Artikel |
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| Sprache: |
Englisch |
| Erschienen: |
2016transfer abstract |
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| Schlagwörter: |
Matrix/fracture permeability and volume Hydraulic fracture half-length Analysis equations from the quadrilinear flow model Capturing secondary fracture effects in triple porosity model |
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| Umfang: |
17 |
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| Übergeordnetes Werk: |
Enthalten in: Iterated Gilbert mosaics - Baccelli, Francois ELSEVIER, 2019, Amsterdam [u.a.] |
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| Übergeordnetes Werk: |
volume:138 ; year:2016 ; pages:201-217 ; extent:17 |
| Links: |
|---|
| DOI / URN: |
10.1016/j.petrol.2015.11.016 |
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ELV024581364 |
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| 245 | 1 | 0 | |a Capturing the effects of secondary fractures on production data using flow regime equations and specialised plots: An uncertainty analysis approach |
| 264 | 1 | |c 2016transfer abstract | |
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| 520 | |a Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. | ||
| 520 | |a Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. | ||
| 650 | 7 | |a Matrix/fracture permeability and volume |2 Elsevier | |
| 650 | 7 | |a Hydraulic fracture half-length |2 Elsevier | |
| 650 | 7 | |a Analysis equations from the quadrilinear flow model |2 Elsevier | |
| 650 | 7 | |a Capturing secondary fracture effects in triple porosity model |2 Elsevier | |
| 650 | 7 | |a Secondary fracture intensity |2 Elsevier | |
| 650 | 7 | |a Specialised rate-normalised pressure analysis plots |2 Elsevier | |
| 650 | 7 | |a Uncertainty reduction in model output parameter |2 Elsevier | |
| 700 | 1 | |a Dehghanpour, Hassan |4 oth | |
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2016 |
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10.1016/j.petrol.2015.11.016 doi GBVA2016014000015.pica (DE-627)ELV024581364 (ELSEVIER)S0920-4105(15)30182-0 DE-627 ger DE-627 rakwb eng 660 660 DE-600 510 VZ 31.70 bkl Ezulike, Obinna Daniel verfasserin aut Capturing the effects of secondary fractures on production data using flow regime equations and specialised plots: An uncertainty analysis approach 2016transfer abstract 17 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. Matrix/fracture permeability and volume Elsevier Hydraulic fracture half-length Elsevier Analysis equations from the quadrilinear flow model Elsevier Capturing secondary fracture effects in triple porosity model Elsevier Secondary fracture intensity Elsevier Specialised rate-normalised pressure analysis plots Elsevier Uncertainty reduction in model output parameter Elsevier Dehghanpour, Hassan oth Enthalten in Elsevier Science Baccelli, Francois ELSEVIER Iterated Gilbert mosaics 2019 Amsterdam [u.a.] (DE-627)ELV008094314 volume:138 year:2016 pages:201-217 extent:17 https://doi.org/10.1016/j.petrol.2015.11.016 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U SSG-OPC-MAT 31.70 Wahrscheinlichkeitsrechnung VZ AR 138 2016 201-217 17 045F 660 |
| spelling |
10.1016/j.petrol.2015.11.016 doi GBVA2016014000015.pica (DE-627)ELV024581364 (ELSEVIER)S0920-4105(15)30182-0 DE-627 ger DE-627 rakwb eng 660 660 DE-600 510 VZ 31.70 bkl Ezulike, Obinna Daniel verfasserin aut Capturing the effects of secondary fractures on production data using flow regime equations and specialised plots: An uncertainty analysis approach 2016transfer abstract 17 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. Matrix/fracture permeability and volume Elsevier Hydraulic fracture half-length Elsevier Analysis equations from the quadrilinear flow model Elsevier Capturing secondary fracture effects in triple porosity model Elsevier Secondary fracture intensity Elsevier Specialised rate-normalised pressure analysis plots Elsevier Uncertainty reduction in model output parameter Elsevier Dehghanpour, Hassan oth Enthalten in Elsevier Science Baccelli, Francois ELSEVIER Iterated Gilbert mosaics 2019 Amsterdam [u.a.] (DE-627)ELV008094314 volume:138 year:2016 pages:201-217 extent:17 https://doi.org/10.1016/j.petrol.2015.11.016 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U SSG-OPC-MAT 31.70 Wahrscheinlichkeitsrechnung VZ AR 138 2016 201-217 17 045F 660 |
| allfields_unstemmed |
10.1016/j.petrol.2015.11.016 doi GBVA2016014000015.pica (DE-627)ELV024581364 (ELSEVIER)S0920-4105(15)30182-0 DE-627 ger DE-627 rakwb eng 660 660 DE-600 510 VZ 31.70 bkl Ezulike, Obinna Daniel verfasserin aut Capturing the effects of secondary fractures on production data using flow regime equations and specialised plots: An uncertainty analysis approach 2016transfer abstract 17 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. Matrix/fracture permeability and volume Elsevier Hydraulic fracture half-length Elsevier Analysis equations from the quadrilinear flow model Elsevier Capturing secondary fracture effects in triple porosity model Elsevier Secondary fracture intensity Elsevier Specialised rate-normalised pressure analysis plots Elsevier Uncertainty reduction in model output parameter Elsevier Dehghanpour, Hassan oth Enthalten in Elsevier Science Baccelli, Francois ELSEVIER Iterated Gilbert mosaics 2019 Amsterdam [u.a.] (DE-627)ELV008094314 volume:138 year:2016 pages:201-217 extent:17 https://doi.org/10.1016/j.petrol.2015.11.016 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U SSG-OPC-MAT 31.70 Wahrscheinlichkeitsrechnung VZ AR 138 2016 201-217 17 045F 660 |
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10.1016/j.petrol.2015.11.016 doi GBVA2016014000015.pica (DE-627)ELV024581364 (ELSEVIER)S0920-4105(15)30182-0 DE-627 ger DE-627 rakwb eng 660 660 DE-600 510 VZ 31.70 bkl Ezulike, Obinna Daniel verfasserin aut Capturing the effects of secondary fractures on production data using flow regime equations and specialised plots: An uncertainty analysis approach 2016transfer abstract 17 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. Matrix/fracture permeability and volume Elsevier Hydraulic fracture half-length Elsevier Analysis equations from the quadrilinear flow model Elsevier Capturing secondary fracture effects in triple porosity model Elsevier Secondary fracture intensity Elsevier Specialised rate-normalised pressure analysis plots Elsevier Uncertainty reduction in model output parameter Elsevier Dehghanpour, Hassan oth Enthalten in Elsevier Science Baccelli, Francois ELSEVIER Iterated Gilbert mosaics 2019 Amsterdam [u.a.] (DE-627)ELV008094314 volume:138 year:2016 pages:201-217 extent:17 https://doi.org/10.1016/j.petrol.2015.11.016 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U SSG-OPC-MAT 31.70 Wahrscheinlichkeitsrechnung VZ AR 138 2016 201-217 17 045F 660 |
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10.1016/j.petrol.2015.11.016 doi GBVA2016014000015.pica (DE-627)ELV024581364 (ELSEVIER)S0920-4105(15)30182-0 DE-627 ger DE-627 rakwb eng 660 660 DE-600 510 VZ 31.70 bkl Ezulike, Obinna Daniel verfasserin aut Capturing the effects of secondary fractures on production data using flow regime equations and specialised plots: An uncertainty analysis approach 2016transfer abstract 17 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. Matrix/fracture permeability and volume Elsevier Hydraulic fracture half-length Elsevier Analysis equations from the quadrilinear flow model Elsevier Capturing secondary fracture effects in triple porosity model Elsevier Secondary fracture intensity Elsevier Specialised rate-normalised pressure analysis plots Elsevier Uncertainty reduction in model output parameter Elsevier Dehghanpour, Hassan oth Enthalten in Elsevier Science Baccelli, Francois ELSEVIER Iterated Gilbert mosaics 2019 Amsterdam [u.a.] (DE-627)ELV008094314 volume:138 year:2016 pages:201-217 extent:17 https://doi.org/10.1016/j.petrol.2015.11.016 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U SSG-OPC-MAT 31.70 Wahrscheinlichkeitsrechnung VZ AR 138 2016 201-217 17 045F 660 |
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capturing the effects of secondary fractures on production data using flow regime equations and specialised plots: an uncertainty analysis approach |
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Capturing the effects of secondary fractures on production data using flow regime equations and specialised plots: An uncertainty analysis approach |
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Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. |
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Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. |
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Many fractured horizontal wells are completed in tight oil/gas or shale gas reservoirs which have significant networks of interconnected secondary fractures. However, the existing linear transient dual- and triple-porosity models do not properly account for secondary fractures. While the dual-porosity model assumes negligible secondary fractures, the linear sequential triple-porosity model assumes negligible fluid transfer between the rock matrix and hydraulic fractures. Hence, the application of these models for production data analysis of fractured horizontal wells could result in unreasonable reservoir/fracture parameter estimates and hydrocarbon forecast. For this reason, the quadrilinear flow model (QFM) was developed to account for matrix–hydraulic fracture communication. Although QFM properly accounts for the contribution of secondary fractures during reservoir depletion, reservoir parameter estimation from its type-curve matching procedure has a high degree of uncertainty. This paper proposes simplified QFM flow regime equations to reduce the uncertainty associated with reservoir parameter estimation. |
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