Reservoir Characterization of the Skagerrak Formation
Master's thesis in Petroleum engineering A petrophyscial evaluation has been generated for three wells penetrating the Skagerrak Formation in the Sleip ner Øst field, the Gungne field, and the Loke field in the Central North Sea, Figure 5 - 1. The wells included in this study were 15/9 - 9, 15/...
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University of Stavanger, Norway
2016
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ftunivstavanger:oai:uis.brage.unit.no:11250/2408351 2023-06-11T04:15:27+02:00 Reservoir Characterization of the Skagerrak Formation Byberg, Ingrid Lehne, Karl Audun 2016-06 application/pdf http://hdl.handle.net/11250/2408351 eng eng University of Stavanger, Norway Masteroppgave/UIS-TN-IPT/2016; http://hdl.handle.net/11250/2408351 143 petroleumsteknologi petroleum engineering reservoir technology reservoarteknologi VDP::Technology: 500::Rock and petroleum disciplines: 510::Petroleum engineering: 512 Master thesis 2016 ftunivstavanger 2023-05-29T16:02:42Z Master's thesis in Petroleum engineering A petrophyscial evaluation has been generated for three wells penetrating the Skagerrak Formation in the Sleip ner Øst field, the Gungne field, and the Loke field in the Central North Sea, Figure 5 - 1. The wells included in this study were 15/9 - 9, 15/9 - 15 and 15/9 - 17. The porosity was the result of calibrating core porosity with the density log. In addition clay volume was included to create an effective porosity. Pressure data from RFT and logs were utilized to find the fluid contact, and the pressure gradients defined the fluid densities used in the evaluation. The calculated permeability, KLOGH, was estimated by regression analysis between the overburden corrected core permeability and core porosity. The result was a poorly correlation. The water saturation modelling has been estimated with three main methods: * use of logs: Indonesia-, Waxman Smits-, and Archie's method. * use of cores * use of a combination of log- and core- evaluated saturations. A pressure transient analysis was performed from DST1 in well 15/9-15, Gungne Field, where the main objectives were to compare the permeability estimated from the test with the core permeability and look at potential barriers in the reservoir. Three different fault models were estimated in an attempt to match the measured data, one fault, parallel fault, intersecting faults. A brief sedimentological evaluation of the Skagerrak Formation was implemented in all three wells based on available log data and core data. The well 6510/7-2 from the Norwegian Sea comprising red beds were compared to the Skagerrak Formation to find that the all the wells are comprising fluvial systems in their respectively Skagerrak Formation. The main difference however was the porosity properties, which implied a much lower porosity in well 6510/7-2. Master Thesis Norwegian Sea University of Stavanger: UiS Brage Loke ENVELOPE(162.550,162.550,-77.483,-77.483) Ner ENVELOPE(6.622,6.622,62.612,62.612) Norwegian Sea |
institution |
Open Polar |
collection |
University of Stavanger: UiS Brage |
op_collection_id |
ftunivstavanger |
language |
English |
topic |
petroleumsteknologi petroleum engineering reservoir technology reservoarteknologi VDP::Technology: 500::Rock and petroleum disciplines: 510::Petroleum engineering: 512 |
spellingShingle |
petroleumsteknologi petroleum engineering reservoir technology reservoarteknologi VDP::Technology: 500::Rock and petroleum disciplines: 510::Petroleum engineering: 512 Byberg, Ingrid Reservoir Characterization of the Skagerrak Formation |
topic_facet |
petroleumsteknologi petroleum engineering reservoir technology reservoarteknologi VDP::Technology: 500::Rock and petroleum disciplines: 510::Petroleum engineering: 512 |
description |
Master's thesis in Petroleum engineering A petrophyscial evaluation has been generated for three wells penetrating the Skagerrak Formation in the Sleip ner Øst field, the Gungne field, and the Loke field in the Central North Sea, Figure 5 - 1. The wells included in this study were 15/9 - 9, 15/9 - 15 and 15/9 - 17. The porosity was the result of calibrating core porosity with the density log. In addition clay volume was included to create an effective porosity. Pressure data from RFT and logs were utilized to find the fluid contact, and the pressure gradients defined the fluid densities used in the evaluation. The calculated permeability, KLOGH, was estimated by regression analysis between the overburden corrected core permeability and core porosity. The result was a poorly correlation. The water saturation modelling has been estimated with three main methods: * use of logs: Indonesia-, Waxman Smits-, and Archie's method. * use of cores * use of a combination of log- and core- evaluated saturations. A pressure transient analysis was performed from DST1 in well 15/9-15, Gungne Field, where the main objectives were to compare the permeability estimated from the test with the core permeability and look at potential barriers in the reservoir. Three different fault models were estimated in an attempt to match the measured data, one fault, parallel fault, intersecting faults. A brief sedimentological evaluation of the Skagerrak Formation was implemented in all three wells based on available log data and core data. The well 6510/7-2 from the Norwegian Sea comprising red beds were compared to the Skagerrak Formation to find that the all the wells are comprising fluvial systems in their respectively Skagerrak Formation. The main difference however was the porosity properties, which implied a much lower porosity in well 6510/7-2. |
author2 |
Lehne, Karl Audun |
format |
Master Thesis |
author |
Byberg, Ingrid |
author_facet |
Byberg, Ingrid |
author_sort |
Byberg, Ingrid |
title |
Reservoir Characterization of the Skagerrak Formation |
title_short |
Reservoir Characterization of the Skagerrak Formation |
title_full |
Reservoir Characterization of the Skagerrak Formation |
title_fullStr |
Reservoir Characterization of the Skagerrak Formation |
title_full_unstemmed |
Reservoir Characterization of the Skagerrak Formation |
title_sort |
reservoir characterization of the skagerrak formation |
publisher |
University of Stavanger, Norway |
publishDate |
2016 |
url |
http://hdl.handle.net/11250/2408351 |
long_lat |
ENVELOPE(162.550,162.550,-77.483,-77.483) ENVELOPE(6.622,6.622,62.612,62.612) |
geographic |
Loke Ner Norwegian Sea |
geographic_facet |
Loke Ner Norwegian Sea |
genre |
Norwegian Sea |
genre_facet |
Norwegian Sea |
op_source |
143 |
op_relation |
Masteroppgave/UIS-TN-IPT/2016; http://hdl.handle.net/11250/2408351 |
_version_ |
1768372288093159424 |