Vis enkel innførsel

dc.contributor.authorNord, Lars Olof
dc.contributor.authorBolland, Olav
dc.date.accessioned2016-10-12T07:45:11Z
dc.date.accessioned2016-10-18T13:00:57Z
dc.date.available2016-10-12T07:45:11Z
dc.date.available2016-10-18T13:00:57Z
dc.date.issued2013
dc.identifier.citationApplied Thermal Engineering 2013, 54(1):85-91nb_NO
dc.identifier.issn1873-5606
dc.identifier.urihttp://hdl.handle.net/11250/2416023
dc.description.abstractCombined cycles applied on offshore oil and gas installations could be an attractive technology on the Norwegian continental shelf to decrease costs related to CO2 emissions. Current power plant technology prevailing on offshore oil- and gas installations is based on simple cycle gas turbines for both electrical and mechanical drive applications. Results based on process simulations showed that net plant efficiency improvements of 26–33% (10–13%-points) compared to simple cycle gas turbines can be achieved when the steam bottoming cycles are designed for compactness and flexibility. The emitted CO2 could be decreased by 20–25% by opting for a combined cycle rather than a simple cycle gas turbine. A clear disadvantage for offshore applications is that the weight-to-power ratio was 60–70% higher for a compact combined cycle than for a simple cycle gas turbine based on results in this study. Once-through heat recovery steam generator technology can be an attractive option when designing a steam bottoming cycle for offshore applications. Its flexibility, the avoidance of steam drums, and, with the right material selection, the possibility to avoid the bypass stack while allowing for dry heat recovery steam generator operation are all advantages for offshore applications. All process models, that were developed for offshore installations in the study presented, included once-through technology. A combined cycle plant layout for an offshore installation with both mechanical drive and generator drive gas turbines was included in the study. This setup allows for flexibility related to changes in demand for both mechanical drive and electricity. With the selected setup, designed for 60 MW shaft power, demand swings of approximately ±10 MW could be handled for either mechanical drive or electrical power while keeping the other drive-mode load constant.nb_NO
dc.language.isoengnb_NO
dc.publisherElseviernb_NO
dc.subjectOnce-through; Rankine cycle; Steam bottoming cycle; Process simulation; Steady-statenb_NO
dc.titleDesign and off-design simulations of combined cycles for offshore oil and gas installationsnb_NO
dc.typeJournal articlenb_NO
dc.typePeer reviewednb_NO
dc.date.updated2016-10-12T07:45:10Z
dc.source.pagenumber85-91nb_NO
dc.source.volume54nb_NO
dc.source.journalApplied Thermal Engineeringnb_NO
dc.source.issue1nb_NO
dc.identifier.doi10.1016/j.applthermaleng.2013.01.022
dc.identifier.cristin1014457
dc.description.localcode© 2016. This manuscript version is made available under the CC-BY-NC-ND 4.0 license http://creativecommons.org/licenses/by-nc-nd/4.0/nb_NO


Tilhørende fil(er)

Thumbnail

Denne innførselen finnes i følgende samling(er)

Vis enkel innførsel