scholarly journals Geology of the Dan field and the Danish North Sea

1975 ◽  
Vol 43 ◽  
pp. 1-24
Author(s):  
F. B Childs ◽  
P.E.C Reed
Keyword(s):  
North Sea ◽  
Upper Cretaceous ◽  
Oil And Gas ◽  
Upper Jurassic ◽  
The North ◽  
Average Porosity ◽  
Probable Source ◽  
Porosity And Permeability ◽  
The North Sea ◽  
Geochemical Studies

The Dan field was discovered in 1971 by the Dansk Undergrunds Consortium's fifteenth offshore wildcat, which encountered oil and gas in Maestrichtian and Danian chalk at the subsea depth of 5790-6565 feet. Production of some 800 BOPD from each of five wells began in July 1972.The field lies on the eastern flank of the North Sea Tertiary basin and near the axis of the Central Graben, a deep trough filled with a thick sequence of Permian to Cretaceous sediments. Upper Cretaceous-Danian chalk at the top of the sequence provides the reservoir for several further hydrocarbon accumulations in offshore Denmark. Geochemical studies indicate that deeper Upper Jurassic marine shales are the probable source beds for these accumulations.The Dan field is a halokinetically induced domal anticline. The chalk reservoir has an average porosity and permeability of 28% and 0.5 millidarcy, respectively. The solution GOR is 600 cu. ft./bbl and the crude oil is 30° API with low sulphur content (0.29%).

scholarly journals The Innes Field, Block 30/24, UK North Sea

2020 ◽  
Vol 52 (1) ◽  
pp. 488-497 ◽  
Author(s):  
J. G. Gluyas ◽  
P. Arkley
Keyword(s):  
North Sea ◽  
Oil And Gas ◽  
Upper Jurassic ◽  
The North ◽  
Start Up ◽  
Central Trough ◽  
The North Sea ◽  
Water Cut ◽  
The Uk ◽  
Oil Company

AbstractThe abandoned Innes Field was within Block 30/24 on the western margin of the Central Trough in the UK sector of the North Sea. Hamilton Brothers Oil Company operated the licence, and Innes was the third commercially viable oil discovery in the block after Argyll and Duncan. It was discovered in 1983 with well 30/24-24. Three appraisal wells were drilled, one of which was successful. Oil occurs in the Early Permian Rotliegend Group sandstones sealed by Zechstein Group dolomites and Upper Jurassic shale.The discovery well and successful appraisal well were used for production. Export of light, gas-rich crude was via a 15 km pipeline to Argyll. Innes was produced using pressure decline. It was abandoned in 1992 having produced 5.8 MMbbl of oil and possibly 9.8 bcf of gas. Water cut was a few percent.Innes was re-examined between 2001 and 2003 by the Tuscan Energy/Acorn Oil and Gas partnership with a view to tying the field back to the newly redeveloped Argyll (Ardmore) Field but marginal economics and financial constraints for the two start-up companies prevented any further activity. Enquest currently owns the licence and the company has redeveloped Argyll/Ardmore, as Alma. There are no plans to redevelop Innes.

The Penguins Cluster, Blocks 211/13a and 211/14, UK North Sea

2020 ◽  
Vol 52 (1) ◽  
pp. 916-927 ◽  
Author(s):  
D. Thorpe ◽  
M. Porter ◽  
T. McKie ◽  
L. J. Ritchie
Keyword(s):  
North Sea ◽  
Middle Jurassic ◽  
Oil And Gas ◽  
Upper Jurassic ◽  
Gas Condensate ◽  
The North ◽  
Average Porosity ◽  
Exploration And Production

AbstractThe Penguins Cluster of fields are owned jointly (50:50) by Shell UK Ltd (Shell) and Esso Exploration and Production UK Ltd (Esso), with Shell as the operator. The cluster was discovered in 1974 and is composed of a combination of oil and gas condensate accumulations located 50–65 km north of the Brent Field, at the northern end of the North Viking Graben. Two main producing reservoirs are present: the Penguins West Field (Penguin A) consists of an Upper Jurassic Magnus Sandstone Member reservoir, while the Penguins East Field (Penguin C, D and E) consists of a Middle Jurassic Brent Group reservoir, underlain by currently undeveloped Statfjord and Triassic (Cormorant) reservoirs. The Magnus reservoir is composed of turbidite sands with an average porosity of 15% and permeabilities of 0.10–300 mD. The Brent reservoirs are composed of deltaic shoreface deposits with an average porosity of 14% and permeabilities of 0.01–1000 mD.The fields were brought on stream in 2003 as a subsea development via what at the time was the world's longest comingled tieback to the Brent Charlie facility. A total of nine producing wells have been drilled from four subsea manifolds, producing c. 78 MMboe to date through depletion drive.

scholarly journals A prospective observational study of why people are medically evacuated from offshore installations in the North Sea

BMJ Open ◽  
2020 ◽  
Vol 10 (7) ◽  
pp. e037558
Author(s):  
Anne Waje-Andreassen ◽  
Øyvind Østerås ◽  
Guttorm Brattebø
Keyword(s):  
Observational Study ◽  
North Sea ◽  
Prospective Observational Study ◽  
Oil And Gas ◽  
Record System ◽  
The North ◽  
Transport Services ◽  
Offshore Installations ◽  
Severity Scores ◽  
The North Sea

ObjectivesFew studies have described evacuations due to medical emergencies from the offshore installations in the North Sea, though efficient medical service is essential for the industrial activities in this area. The major oil- and gas-producing companies’ search and rescue (SAR) service is responsible for medical evacuations. Using a prospective approach, we describe the characteristics of patients evacuated by SAR.Design and settingA prospective observational study of the offshore primary care provided by SAR in the North Sea.MethodsPatients were identified by linking flight information from air transport services in 2015/2016 and the company’s medical record system. Standardised forms filled out by SAR nurses during the evacuation were also analysed. In-hospital information was obtained retrospectively from Haukeland University Hospital’s information system.ResultsA total of 381 persons (88% men) were evacuated during the study period. Twenty-seven per cent of missions were due to chest pain and 18% due to trauma. The mean age was 46.0 years. Severity scores were higher for cases due to medical conditions compared with trauma, but the scores were relatively low compared with onshore emergency missions. The busiest months were May, July and December. Weekends were the busiest days.ConclusionThree times as many evacuations from offshore installations are performed due to acute illness than trauma, and cardiac problems are the most common. Although most patients are not severely physiologically deranged, the study documents a need for competent SAR services 24 hours a day year-round. Training and certification should be tailored for the SAR service, as the offshore health service structure and geography differs from the structure onshore.

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