Yme, A Marginal-Field Development in the North Sea

Gjøa was the largest field development project in Norway in 2010. Gjøa was proven in 1989 and are now being developed together with nearby Vega satellites. The combined reserves are estiThe recent Gjøa field development in the North Sea has many features that are relevant for the oil and gas developments north of Western Australia. While the field location is not very similar to the north of Western Australia, the field development solution is very relevant. Several subsea clusters are tied back to a semi-submersible platform with export of gas and condensate via pipelines to shore. Other aspects to the project that are relevant to Western Australia are split location engineering between Norway and India, fabrication of the hull in Korea and subsequent heavy lift transport to the assembly yard, pre-installation of the mooring system, and tow to field with ocean going tug boats. The semi concept, which was used for the Gjøa development, is a mature technology with few technical challenges on a conceptual level. On the other hand the building of an oil and gas platform for A$2 billion has many challenges, both economical and technical, that have to be solved to have a successful project for both the client and the contractor.

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The Buzzard Field, Blocks 19/5a, 19/10a, 20/1 and 20/6a, UK North Sea

Geological Society London Memoirs ◽

10.1144/m52-2019-17 ◽

2020 ◽

Vol 52 (1) ◽

pp. 691-704 ◽

Cited By ~ 1

Author(s):

E. E. Taylor ◽

N. J. Webb ◽

C. J. Stevenson ◽

J. R. Henderson ◽

A. Kovac ◽

...

Keyword(s):

North Sea ◽

Upper Jurassic ◽

Depositional Model ◽

Performance Expectations ◽

North West ◽

Field Development ◽

The North ◽

Moray Firth ◽

The North Sea ◽

Clay Formation

AbstractThe Buzzard Field remains the largest UK Continental Shelf oil discovery in the last 25 years. The field is located in the Outer Moray Firth of the North Sea and comprises stacked Upper Jurassic turbidite reservoirs of Late Kimmeridgian–Mid Volgian age, encased within Kimmeridge Clay Formation mudstones. The stratigraphic trap is produced by pinchout of the reservoir layers to the north, west and south. Production commenced in January 2007 and the field has subsequently produced 52% over the estimated reserves at commencement of development, surpassing initial performance expectations. Phase I drilling was completed in 2014 with 38 wells drilled from 36 platform slots. Platform drilling recommenced in 2018, followed in 2019 by Phase II drilling from a new northern manifold location.The evolution of the depositional model has been a key aspect of field development. Integration of production surveillance and dynamic data identified shortcomings in the appraisal depositional model. A sedimentological study based on core reinterpretation created an updated depositional model, which was then integrated with seismic and production data. The new depositional model is better able to explain non-uniform water sweep in the field resulting from a more complex sandbody architecture of stacked channels prograding over underlying lobes.

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The Leman Field, Blocks 49/26, 49/27, 49/28, 53/1, 53/2, UK North Sea

Geological Society London Memoirs ◽

10.1144/gsl.mem.1991.014.01.56 ◽

1991 ◽

Vol 14 (1) ◽

pp. 451-458 ◽

Cited By ~ 5

Author(s):

A. P. Hillier ◽

B. P. J. Williams

Keyword(s):

North Sea ◽

Old Field ◽

Gas Field ◽

Field Development ◽

Dune Sands ◽

The North ◽

The North Sea ◽

To Come ◽

The Uk ◽

Estimated Ultimate Recovery

AbstractDiscovered in 1966 and starting production in 1968, Leman was the second gas field to come into production in the UK sector of the North Sea. It is classified as a giant field with an estimated ultimate recovery of 11 500 BCF of gas in the aeolian dune sands of the Rotliegend Group. The field extends over five blocks and is being developed by two groups with Shell and Amoco being the operators. Despite being such an old field development drilling is still ongoing in the field with the less permeable northwest area currently being developed.

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The Cyrus Field, Block 16/28, UK North Sea

Geological Society London Memoirs ◽

10.1144/gsl.mem.1991.014.01.36 ◽

1991 ◽

Vol 14 (1) ◽

pp. 295-300 ◽

Cited By ~ 2

Author(s):

D. G. Mound ◽

I. D. Robertson ◽

R. J. Wallis

Keyword(s):

North Sea ◽

Field Development ◽

Fine Grained ◽

The North ◽

Offshore Production ◽

Fault Block ◽

Single Well ◽

The North Sea ◽

Net To Gross ◽

The Uk

AbstractThe Cyrus Oilfield is located in Block 16/28 of the UK sector of the North Sea approximately 250 km (155 miles) NE of Aberdeen and 55 km (34 miles) NE of the Forties Field. The trap consists of a broad, very low relief four-way dip closure developed over a deeper tilted fault block. The reservoir consists of submarine-fan sandstones of late Palaeocene age, belonging to the Andrew Formation. Provenance was to the NW resulting from the early Tertiary sea-level fall which exposed the East Shetland Platform. The reservoir has been sub-divided into two zones, an upper zone of interbedded sandstones and mudstones with net to gross ratios of 0.4 to 0.6 and sandstone porositites of 12% to 18%, and a lower zone of massive fine-grained sandstones plus subordinate thin shales and limestones, with net to gross ratios in excess of 0.9 and porosities averaging 20%. The reservoir is filled with undersaturated oil of 35° API and is normally pressured. The estimate of initial oil-in-place is 75 MMBBL. Development of the field is centred on the use of BP's SWOPS (Single Well Offshore Production System) vessel using two horizontal field development wells which feed into a single seabed template for offtake. Ultimate recovery from the field is estimated to be approximately 12 MMBBL.

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