Rate of Hydrate Inhibitor in Long Subsea Pipelines
This thesis is divided into several parts. The first part deals with hydrate theory and where hydrates form in the gas-and oil-dominated systems. A review of how hydrate plugs is formed and a method for removing hydrate plugs safely is also included.Simplified HYSYS models of the upstream part of Or...
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Institutt for petroleumsteknologi og anvendt geofysikk
2012
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ftntnutrondheimi:oai:ntnuopen.ntnu.no:11250/239808 2023-05-15T18:20:12+02:00 Rate of Hydrate Inhibitor in Long Subsea Pipelines Christiansen, Håkon Eidem Gudmundsson, Jon Steinar Norges teknisk-naturvitenskapelige universitet, Fakultet for ingeniørvitenskap og teknologi, Institutt for petroleumsteknologi og anvendt geofysikk 2012 http://hdl.handle.net/11250/239808 eng eng Institutt for petroleumsteknologi og anvendt geofysikk 566280 ntnudaim:7871 http://hdl.handle.net/11250/239808 115 ntnudaim:7871 MTGEOP Geofag og petroleumsteknologi Petroleumsproduksjon Master thesis 2012 ftntnutrondheimi 2019-09-17T06:48:52Z This thesis is divided into several parts. The first part deals with hydrate theory and where hydrates form in the gas-and oil-dominated systems. A review of how hydrate plugs is formed and a method for removing hydrate plugs safely is also included.Simplified HYSYS models of the upstream part of Ormen Lange and Snøhvit gas fields on the Norwegian Continental Shelf constituted the basis for answering the second part of the task. Data from private conversations, reports, slide presentations, and other documents were used to create the models.Based on the models, calculations were made on the injection rate and storage capacity of mono ethylene glycol (MEG) on Ormen Lange and Snøhvit. The same models and calculation methods were used to determine injection rates for both methanol (MeOH) and MEG on the same fields. All the results combined with literature were then used to compare the inhibitors properties to determine which one was best suited for use on the current fields. During rate calculations several cases were made to determine which factors have the greatest impact on the amount of inhibitor needed.It was found that hydrates are formed on the pipe wall in gas dominated pipelines, while they are formed in the bulk flow in oil-dominated systems. The heat transfer coefficient and the seabed temperature have great influence on the amount of inhibitor needed. MEG-rate and storage capacity on Snøhvit are very large. Ormen Lange needs a larger inhibitor injection rate than Snøhvit. MEG is better suited than MeOH as an inhibitor of long-distance multi-phase tie-backs such as Ormen Lange and Snøhvit. Master Thesis Snøhvit NTNU Open Archive (Norwegian University of Science and Technology) |
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Open Polar |
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NTNU Open Archive (Norwegian University of Science and Technology) |
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ftntnutrondheimi |
language |
English |
topic |
ntnudaim:7871 MTGEOP Geofag og petroleumsteknologi Petroleumsproduksjon |
spellingShingle |
ntnudaim:7871 MTGEOP Geofag og petroleumsteknologi Petroleumsproduksjon Christiansen, Håkon Eidem Rate of Hydrate Inhibitor in Long Subsea Pipelines |
topic_facet |
ntnudaim:7871 MTGEOP Geofag og petroleumsteknologi Petroleumsproduksjon |
description |
This thesis is divided into several parts. The first part deals with hydrate theory and where hydrates form in the gas-and oil-dominated systems. A review of how hydrate plugs is formed and a method for removing hydrate plugs safely is also included.Simplified HYSYS models of the upstream part of Ormen Lange and Snøhvit gas fields on the Norwegian Continental Shelf constituted the basis for answering the second part of the task. Data from private conversations, reports, slide presentations, and other documents were used to create the models.Based on the models, calculations were made on the injection rate and storage capacity of mono ethylene glycol (MEG) on Ormen Lange and Snøhvit. The same models and calculation methods were used to determine injection rates for both methanol (MeOH) and MEG on the same fields. All the results combined with literature were then used to compare the inhibitors properties to determine which one was best suited for use on the current fields. During rate calculations several cases were made to determine which factors have the greatest impact on the amount of inhibitor needed.It was found that hydrates are formed on the pipe wall in gas dominated pipelines, while they are formed in the bulk flow in oil-dominated systems. The heat transfer coefficient and the seabed temperature have great influence on the amount of inhibitor needed. MEG-rate and storage capacity on Snøhvit are very large. Ormen Lange needs a larger inhibitor injection rate than Snøhvit. MEG is better suited than MeOH as an inhibitor of long-distance multi-phase tie-backs such as Ormen Lange and Snøhvit. |
author2 |
Gudmundsson, Jon Steinar Norges teknisk-naturvitenskapelige universitet, Fakultet for ingeniørvitenskap og teknologi, Institutt for petroleumsteknologi og anvendt geofysikk |
format |
Master Thesis |
author |
Christiansen, Håkon Eidem |
author_facet |
Christiansen, Håkon Eidem |
author_sort |
Christiansen, Håkon Eidem |
title |
Rate of Hydrate Inhibitor in Long Subsea Pipelines |
title_short |
Rate of Hydrate Inhibitor in Long Subsea Pipelines |
title_full |
Rate of Hydrate Inhibitor in Long Subsea Pipelines |
title_fullStr |
Rate of Hydrate Inhibitor in Long Subsea Pipelines |
title_full_unstemmed |
Rate of Hydrate Inhibitor in Long Subsea Pipelines |
title_sort |
rate of hydrate inhibitor in long subsea pipelines |
publisher |
Institutt for petroleumsteknologi og anvendt geofysikk |
publishDate |
2012 |
url |
http://hdl.handle.net/11250/239808 |
genre |
Snøhvit |
genre_facet |
Snøhvit |
op_source |
115 |
op_relation |
566280 ntnudaim:7871 http://hdl.handle.net/11250/239808 |
_version_ |
1766197695636045824 |