Dépouillements

Development of unsteady-state Weymouth equations for gas volumetric flow rate in horizontal and inclined pipes / T. A. Adeosun in Journal of natural gas science and engineering, Vol. 1 N° 4-5 (Novembre 2009) 

Public ISBD [article]  in Journal of natural gas science and engineering > Vol. 1 N° 4-5 (Novembre 2009) . - pp. 113-117 Titre : Development of unsteady-state Weymouth equations for gas volumetric flow rate in horizontal and inclined pipes Type de document : texte imprimé Auteurs : T. A. Adeosun, Auteur ; O.A. Olatunde, Auteur ; J. O. Aderohunmu, Auteur Article en page(s) : pp. 113-117 Note générale : Génie Chimique Langues : Anglais (eng) Mots-clés : Flow  rate  Unsteady-State  Weymouth Index. décimale : 665.7 Résumé : Calculations of Unsteady-State Gas volumetric flow rate in pipes occur more frequently in the design and operational analysis of natural gas systems. Most of the existing gas pipelines design procedures on Weymouth Equations are based on steady-state flow equations. Hence there is the need to develop equations capable of calculating the unsteady-state gas volumetric flow rate in horizontal and inclined pipes. This paper presents unsteady-state Weymouth Equations for flow of natural gas in long pipelines without neglecting any term in the momentum equation. The analytical solutions of the resulting differential equations are obtained in the form of Unsteady-State Weymouth equations. The equations give functional relationship between flow rate, inlet pressure and outlet pressure at any given time. The effect of pressure drop per segment on gas flow rate is presented. The new Weymouth Equations yield results close to steady-state flow and is able to account for the initial transience in gas volumetric flow rate. The equations considerably enhance gas pipeline design in terms of both ease of usage and accuracy. A simple computer program in FORTRAN is developed to handle these calculations. DEWEY : 665.7 ISSN : 1875-5100 En ligne : http://www.sciencedirect.com/science?_ob=PublicationURL&_tockey=%23TOC%2356453%2 [...] [article] Development of unsteady-state Weymouth equations for gas volumetric flow rate in horizontal and inclined pipes [texte imprimé] / T. A. Adeosun, Auteur ; O.A. Olatunde, Auteur ; J. O. Aderohunmu, Auteur . - pp. 113-117. Génie Chimique Langues : Anglais (eng) in Journal of natural gas science and engineering > Vol. 1 N° 4-5 (Novembre 2009) . - pp. 113-117 Mots-clés : Flow  rate  Unsteady-State  Weymouth Index. décimale : 665.7 Résumé : Calculations of Unsteady-State Gas volumetric flow rate in pipes occur more frequently in the design and operational analysis of natural gas systems. Most of the existing gas pipelines design procedures on Weymouth Equations are based on steady-state flow equations. Hence there is the need to develop equations capable of calculating the unsteady-state gas volumetric flow rate in horizontal and inclined pipes. This paper presents unsteady-state Weymouth Equations for flow of natural gas in long pipelines without neglecting any term in the momentum equation. The analytical solutions of the resulting differential equations are obtained in the form of Unsteady-State Weymouth equations. The equations give functional relationship between flow rate, inlet pressure and outlet pressure at any given time. The effect of pressure drop per segment on gas flow rate is presented. The new Weymouth Equations yield results close to steady-state flow and is able to account for the initial transience in gas volumetric flow rate. The equations considerably enhance gas pipeline design in terms of both ease of usage and accuracy. A simple computer program in FORTRAN is developed to handle these calculations. DEWEY : 665.7 ISSN : 1875-5100 En ligne : http://www.sciencedirect.com/science?_ob=PublicationURL&_tockey=%23TOC%2356453%2 [...]

Using artificial neural networks to generate synthetic well logs / Luisa Rolon in Journal of natural gas science and engineering, Vol. 1 N° 4-5 (Novembre 2009) 

Public ISBD [article]  in Journal of natural gas science and engineering > Vol. 1 N° 4-5 (Novembre 2009) . - pp. 118-133 Titre : Using artificial neural networks to generate synthetic well logs Type de document : texte imprimé Auteurs : Luisa Rolon, Auteur ; Shahab D. Mohaghegh, Auteur ; Sam Ameri, Auteur Article en page(s) : pp. 118-133 Note générale : Génie Chimique Langues : Anglais (eng) Mots-clés : Synthetic  logs  Neural  networks  Reservoir  characterization  Well  logs  Artificial  intelligence  Petrophysics Index. décimale : 665.7 Résumé : A methodology to generate synthetic wireline logs is presented. Synthetic logs can help to analyze the reservoir properties in areas where the set of logs that are necessary, are absent or incomplete. The approach presented involves the use of artificial neural networks as the main tool, in conjunction with data obtained from conventional wireline logs. Implementation of this approach aims to reduce costs to companies. Development of the neural network model was completed using Generalized Regression Neural Network, and wireline logs from four wells that included gamma ray, density, neutron, and resistivity logs. Synthetic logs were generated through two different exercises. Exercise one involved all four wells for training, calibration and verification process. The second exercise used three wells for training and calibration and the fourth well was used for verification. In order to demonstrate the robustness of the methodology, three different combinations of inputs/outputs were chosen to train the network. In combination “A” the resistivity log was the output and density, gamma ray, and neutron logs, and the coordinates and depths (XYZ) the inputs. In combination “B” the density log was output and the resistivity, the gamma ray, and the neutron logs, and XYZ were the inputs, and in combination “C” the neutron log was the output while the resistivity, the gamma ray, and the density logs, and XYZ were the inputs. After development of the neural network model, synthetic logs with a reasonable degree of accuracy were generated. Results indicate that the best performance was obtained for combination “A” of inputs and outputs, then for combination “C”, and finally for combination “B”. In addition, it was determined that accuracy of synthetic logs is favored by interpolation of data. It was also demonstrated that using neural network to generate synthetic well logs is far more superior when compared to conventional approaches such as multiple-regression. DEWEY : 665.7 ISSN : 1875-5100 En ligne : http://www.sciencedirect.com/science?_ob=PublicationURL&_tockey=%23TOC%2356453%2 [...] [article] Using artificial neural networks to generate synthetic well logs [texte imprimé] / Luisa Rolon, Auteur ; Shahab D. Mohaghegh, Auteur ; Sam Ameri, Auteur . - pp. 118-133. Génie Chimique Langues : Anglais (eng) in Journal of natural gas science and engineering > Vol. 1 N° 4-5 (Novembre 2009) . - pp. 118-133 Mots-clés : Synthetic  logs  Neural  networks  Reservoir  characterization  Well  logs  Artificial  intelligence  Petrophysics Index. décimale : 665.7 Résumé : A methodology to generate synthetic wireline logs is presented. Synthetic logs can help to analyze the reservoir properties in areas where the set of logs that are necessary, are absent or incomplete. The approach presented involves the use of artificial neural networks as the main tool, in conjunction with data obtained from conventional wireline logs. Implementation of this approach aims to reduce costs to companies. Development of the neural network model was completed using Generalized Regression Neural Network, and wireline logs from four wells that included gamma ray, density, neutron, and resistivity logs. Synthetic logs were generated through two different exercises. Exercise one involved all four wells for training, calibration and verification process. The second exercise used three wells for training and calibration and the fourth well was used for verification. In order to demonstrate the robustness of the methodology, three different combinations of inputs/outputs were chosen to train the network. In combination “A” the resistivity log was the output and density, gamma ray, and neutron logs, and the coordinates and depths (XYZ) the inputs. In combination “B” the density log was output and the resistivity, the gamma ray, and the neutron logs, and XYZ were the inputs, and in combination “C” the neutron log was the output while the resistivity, the gamma ray, and the density logs, and XYZ were the inputs. After development of the neural network model, synthetic logs with a reasonable degree of accuracy were generated. Results indicate that the best performance was obtained for combination “A” of inputs and outputs, then for combination “C”, and finally for combination “B”. In addition, it was determined that accuracy of synthetic logs is favored by interpolation of data. It was also demonstrated that using neural network to generate synthetic well logs is far more superior when compared to conventional approaches such as multiple-regression. DEWEY : 665.7 ISSN : 1875-5100 En ligne : http://www.sciencedirect.com/science?_ob=PublicationURL&_tockey=%23TOC%2356453%2 [...]

Distributed fibre optic sensors for pipeline protection / Femi Tanimola in Journal of natural gas science and engineering, Vol. 1 N° 4-5 (Novembre 2009) 

Public ISBD [article]  in Journal of natural gas science and engineering > Vol. 1 N° 4-5 (Novembre 2009) . - pp. 134-143 Titre : Distributed fibre optic sensors for pipeline protection Type de document : texte imprimé Auteurs : Femi Tanimola, Auteur ; David Hill, Auteur Article en page(s) : pp. 134-143 Note générale : Génie Chimique Langues : Anglais (eng) Mots-clés : DTS  –  Distributed  temperature  sensing  DAS  –  Distributed  acoustic  sensing  OTDR  –  Optical  time  domain  reflectometer  SCADA  –  Supervisory  control  and  data  acquisition Index. décimale : 665.7 Résumé : Pipeline leakage and intrusion detection continue to be a difficult issue because existing leak detection methods and the traditional methods of guarding pipelines have proven inadequate in the prevention of leaks and deterring third party intrusion into pipelines and plant facilities. The application of fibre optic leak detection and third party intruder detection methods have been successfully demonstrated to provide non-intrusive digital pipeline monitoring by acting as an early warning system, allowing operators to act swiftly in the event of a pipeline leakage or intrusion into a plant area or leakage into the environment. The ability to interface with existing client DCS and SCADA system also provides automated input from fibre optic monitoring systems where product leakage requires prompt closure of pipeline valves before large spills occur. This paper explains the principle of Leak Detection and Third Party Intruder Detection using fibre optics distributed temperature sensing (DTS) with examples of recent LNG and LPG pipeline leak detection installations and the outcomes of fibre optic distributed acoustic sensing (DAS) intruder monitoring case studies with a view to improving pipeline protection and thus increase pipeline productivity and integrity, while offering protection of the environment. DEWEY : 665.7 ISSN : 1875-5100 En ligne : http://www.sciencedirect.com/science?_ob=PublicationURL&_tockey=%23TOC%2356453%2 [...] [article] Distributed fibre optic sensors for pipeline protection [texte imprimé] / Femi Tanimola, Auteur ; David Hill, Auteur . - pp. 134-143. Génie Chimique Langues : Anglais (eng) in Journal of natural gas science and engineering > Vol. 1 N° 4-5 (Novembre 2009) . - pp. 134-143 Mots-clés : DTS  –  Distributed  temperature  sensing  DAS  –  Distributed  acoustic  sensing  OTDR  –  Optical  time  domain  reflectometer  SCADA  –  Supervisory  control  and  data  acquisition Index. décimale : 665.7 Résumé : Pipeline leakage and intrusion detection continue to be a difficult issue because existing leak detection methods and the traditional methods of guarding pipelines have proven inadequate in the prevention of leaks and deterring third party intrusion into pipelines and plant facilities. The application of fibre optic leak detection and third party intruder detection methods have been successfully demonstrated to provide non-intrusive digital pipeline monitoring by acting as an early warning system, allowing operators to act swiftly in the event of a pipeline leakage or intrusion into a plant area or leakage into the environment. The ability to interface with existing client DCS and SCADA system also provides automated input from fibre optic monitoring systems where product leakage requires prompt closure of pipeline valves before large spills occur. This paper explains the principle of Leak Detection and Third Party Intruder Detection using fibre optics distributed temperature sensing (DTS) with examples of recent LNG and LPG pipeline leak detection installations and the outcomes of fibre optic distributed acoustic sensing (DAS) intruder monitoring case studies with a view to improving pipeline protection and thus increase pipeline productivity and integrity, while offering protection of the environment. DEWEY : 665.7 ISSN : 1875-5100 En ligne : http://www.sciencedirect.com/science?_ob=PublicationURL&_tockey=%23TOC%2356453%2 [...]

Evaluation of methane emissions from polyethylene gas distribution systems at medium pressure / Jorge Barroso in Journal of natural gas science and engineering, Vol. 1 N° 4-5 (Novembre 2009) 

Public ISBD [article]  in Journal of natural gas science and engineering > Vol. 1 N° 4-5 (Novembre 2009) . - pp. 144-153 Titre : Evaluation of methane emissions from polyethylene gas distribution systems at medium pressure Type de document : texte imprimé Auteurs : Jorge Barroso, Auteur ; Juan M. Solis, Auteur ; Javier Ballester, Auteur Article en page(s) : pp. 144-153 Note générale : Génie Chimique Langues : Anglais (eng) Mots-clés : Gas  distribution  Methane  emissions  Leakage Index. décimale : 665.7 Résumé : This paper presents new results on the characterisation of leak rates in polyethylene gas distribution systems. The work was motivated by the need to update the emission factors used to estimate methane emissions in Spanish networks. There are included a survey of the emission factors accepted in other countries as well as a detailed characterisation of the leak rates in polyethylene medium pressure mains. The pressure variation method was selected for the field tests, which were fulfilled in 51 Spanish and 13 Mexican sites. The results obtained confirm that the average emission factor for polyethylene gas distribution networks working at medium pressure is 0.46 ± 0.15 Nm3 year−1 m−1. Based on the results of this study, a new calculation methodology has been developed. On the other hand, the experimental data reported here are thought to be representative of polyethylene medium pressure distribution lines in other countries, and might be useful to check existing leak calculation methods. DEWEY : 665.7 ISSN : 1875-5100 En ligne : http://www.sciencedirect.com/science?_ob=PublicationURL&_tockey=%23TOC%2356453%2 [...] [article] Evaluation of methane emissions from polyethylene gas distribution systems at medium pressure [texte imprimé] / Jorge Barroso, Auteur ; Juan M. Solis, Auteur ; Javier Ballester, Auteur . - pp. 144-153. Génie Chimique Langues : Anglais (eng) in Journal of natural gas science and engineering > Vol. 1 N° 4-5 (Novembre 2009) . - pp. 144-153 Mots-clés : Gas  distribution  Methane  emissions  Leakage Index. décimale : 665.7 Résumé : This paper presents new results on the characterisation of leak rates in polyethylene gas distribution systems. The work was motivated by the need to update the emission factors used to estimate methane emissions in Spanish networks. There are included a survey of the emission factors accepted in other countries as well as a detailed characterisation of the leak rates in polyethylene medium pressure mains. The pressure variation method was selected for the field tests, which were fulfilled in 51 Spanish and 13 Mexican sites. The results obtained confirm that the average emission factor for polyethylene gas distribution networks working at medium pressure is 0.46 ± 0.15 Nm3 year−1 m−1. Based on the results of this study, a new calculation methodology has been developed. On the other hand, the experimental data reported here are thought to be representative of polyethylene medium pressure distribution lines in other countries, and might be useful to check existing leak calculation methods. DEWEY : 665.7 ISSN : 1875-5100 En ligne : http://www.sciencedirect.com/science?_ob=PublicationURL&_tockey=%23TOC%2356453%2 [...]

Casing strength degradation due to torsion residual stress in casing drilling / Zhao Zengxin in Journal of natural gas science and engineering, Vol. 1 N° 4-5 (Novembre 2009) 

Public ISBD [article]  in Journal of natural gas science and engineering > Vol. 1 N° 4-5 (Novembre 2009) . - pp. 154-157 Titre : Casing strength degradation due to torsion residual stress in casing drilling Type de document : texte imprimé Auteurs : Zhao Zengxin, Auteur ; Gao Deli, Auteur Article en page(s) : pp. 154-157 Note générale : Génie Chimique Langues : Anglais (eng) Mots-clés : Casing  drilling  Torque  Torsion  status  Residual  stress  Collapse  strength Index. décimale : 665.7 Résumé : Casing string is rotated by torque from wellhead during casing drilling. The method to determine casing torsion status under various torques in casing drilling was discussed. There are three different torsion statuses under different torques, including elastic torsion, elastoplastic torsion and plastic torsion. The residual stress distribution was also discussed under different torques. The average residual stress under elastoplastic and plastic torsion status was calculated respectively; The modified casing collapse strength formula was derived considering the effect of residual stress. The analysis of calculation results indicates that the residual stress caused the collapse strength to decrease 0.033% under elastoplastic torsion, and effects of residual stress on casing strength can be neglected when there is no geometry shape changes in the casing. DEWEY : 665.7 ISSN : 1875-5100 En ligne : http://www.sciencedirect.com/science?_ob=PublicationURL&_tockey=%23TOC%2356453%2 [...] [article] Casing strength degradation due to torsion residual stress in casing drilling [texte imprimé] / Zhao Zengxin, Auteur ; Gao Deli, Auteur . - pp. 154-157. Génie Chimique Langues : Anglais (eng) in Journal of natural gas science and engineering > Vol. 1 N° 4-5 (Novembre 2009) . - pp. 154-157 Mots-clés : Casing  drilling  Torque  Torsion  status  Residual  stress  Collapse  strength Index. décimale : 665.7 Résumé : Casing string is rotated by torque from wellhead during casing drilling. The method to determine casing torsion status under various torques in casing drilling was discussed. There are three different torsion statuses under different torques, including elastic torsion, elastoplastic torsion and plastic torsion. The residual stress distribution was also discussed under different torques. The average residual stress under elastoplastic and plastic torsion status was calculated respectively; The modified casing collapse strength formula was derived considering the effect of residual stress. The analysis of calculation results indicates that the residual stress caused the collapse strength to decrease 0.033% under elastoplastic torsion, and effects of residual stress on casing strength can be neglected when there is no geometry shape changes in the casing. DEWEY : 665.7 ISSN : 1875-5100 En ligne : http://www.sciencedirect.com/science?_ob=PublicationURL&_tockey=%23TOC%2356453%2 [...]

Experimental investigation of the velocity-dependent relative permeability and sweep efficiency of supercritical CO2 injection into gas condensate reservoirs / Abdullah Al Abri in Journal of natural gas science and engineering, Vol. 1 N° 4-5 (Novembre 2009) 

Public ISBD [article]  in Journal of natural gas science and engineering > Vol. 1 N° 4-5 (Novembre 2009) . - pp. 158-164 Titre : Experimental investigation of the velocity-dependent relative permeability and sweep efficiency of supercritical CO2 injection into gas condensate reservoirs Type de document : texte imprimé Auteurs : Abdullah Al Abri, Auteur ; Sidiq Hiwa, Auteur ; Amin Robert, Auteur Article en page(s) : pp. 158-164 Note générale : Génie Chimique Langues : Anglais (eng) Mots-clés : Natural  gas  and  condensate  recovery  Relative  permeability  Sweep  efficiency  CO2  injection Index. décimale : 665.7 Résumé : This paper presents a laboratory investigation of the velocity-dependent relative permeability (VDRP) and recovery efficiency of supercritical CO2 injection into gas condensate reservoirs for enhanced recovery purposes. A high pressure high temperature coreflood facility was commissioned to duplicate reservoir conditions and to conduct two systematic investigation lines of displacement tests on sandstone cores with varying injection velocities of 10, 7, 5, 2 and 1 cm/h; equivalent to typical field interstitial velocities of around 8, 5.5, 4, 1.6 and 0.8 ft/day. One unsteady-state displacement procedure was used to displace dead condensate with SCCO2 at 95 °C while the other set simulates SCCO2 injection to sweep natural gas at 160 °C. These measurements form a single element of an extensive enhanced oil recovery project for a field in Western Australasia. The coreflooding results indicate that slower displacement flow rates (i.e. representative of flow behaviours deep in reservoirs or low injection rates) yield greater condensate ultimate recovery (13.93% OOIP total difference). This negative velocity coupling leads also to delayed gas breakthrough (0.16 PVI total difference compared to 10 cm/h BT). These experimental observations benchmark existing simulation studies ([Crandall, 2007] and [Ferer et al., 2004]). The natural gas displacements by SCCO2, however, interestingly, show an opposite response. Faster displacement rates demotivate diffusion and dispersion of gases and thus yield a better sweep efficiency and later breakthrough (SCCO2 breaks at effluent around four times later at 10 cm/h compared to 1 cm/h). This positive velocity coupling improves relative permeability data (around 80% increase in relative permeability at 10 cm/h compared to that at 1 cm/h). Although the need for an accelerated hydrocarbons production to meet market demands may stimulate the use of higher SCCO2 injection rates there will, however, be a trade-off between incremental methane recovery and the produced condensate sweep efficiency. This work serves as a ‘building-block’ to the essential practical understanding of the displacement flow rates associated with improved natural gas and condensate recovery by SCCO2 injection. DEWEY : 665.7 ISSN : 1875-5100 En ligne : http://www.sciencedirect.com/science?_ob=PublicationURL&_tockey=%23TOC%2356453%2 [...] [article] Experimental investigation of the velocity-dependent relative permeability and sweep efficiency of supercritical CO2 injection into gas condensate reservoirs [texte imprimé] / Abdullah Al Abri, Auteur ; Sidiq Hiwa, Auteur ; Amin Robert, Auteur . - pp. 158-164. Génie Chimique Langues : Anglais (eng) in Journal of natural gas science and engineering > Vol. 1 N° 4-5 (Novembre 2009) . - pp. 158-164 Mots-clés : Natural  gas  and  condensate  recovery  Relative  permeability  Sweep  efficiency  CO2  injection Index. décimale : 665.7 Résumé : This paper presents a laboratory investigation of the velocity-dependent relative permeability (VDRP) and recovery efficiency of supercritical CO2 injection into gas condensate reservoirs for enhanced recovery purposes. A high pressure high temperature coreflood facility was commissioned to duplicate reservoir conditions and to conduct two systematic investigation lines of displacement tests on sandstone cores with varying injection velocities of 10, 7, 5, 2 and 1 cm/h; equivalent to typical field interstitial velocities of around 8, 5.5, 4, 1.6 and 0.8 ft/day. One unsteady-state displacement procedure was used to displace dead condensate with SCCO2 at 95 °C while the other set simulates SCCO2 injection to sweep natural gas at 160 °C. These measurements form a single element of an extensive enhanced oil recovery project for a field in Western Australasia. The coreflooding results indicate that slower displacement flow rates (i.e. representative of flow behaviours deep in reservoirs or low injection rates) yield greater condensate ultimate recovery (13.93% OOIP total difference). This negative velocity coupling leads also to delayed gas breakthrough (0.16 PVI total difference compared to 10 cm/h BT). These experimental observations benchmark existing simulation studies ([Crandall, 2007] and [Ferer et al., 2004]). The natural gas displacements by SCCO2, however, interestingly, show an opposite response. Faster displacement rates demotivate diffusion and dispersion of gases and thus yield a better sweep efficiency and later breakthrough (SCCO2 breaks at effluent around four times later at 10 cm/h compared to 1 cm/h). This positive velocity coupling improves relative permeability data (around 80% increase in relative permeability at 10 cm/h compared to that at 1 cm/h). Although the need for an accelerated hydrocarbons production to meet market demands may stimulate the use of higher SCCO2 injection rates there will, however, be a trade-off between incremental methane recovery and the produced condensate sweep efficiency. This work serves as a ‘building-block’ to the essential practical understanding of the displacement flow rates associated with improved natural gas and condensate recovery by SCCO2 injection. DEWEY : 665.7 ISSN : 1875-5100 En ligne : http://www.sciencedirect.com/science?_ob=PublicationURL&_tockey=%23TOC%2356453%2 [...]

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