Workflows & Considerations for CO2 Injection in a Highly Depleted Gas Field in the Southern North Sea

2011 ◽  
Author(s):  
Craig M. Webster ◽  
Yuping Zhang ◽  
Dorothy Park ◽  
Kate Gibbons
Keyword(s):  
North Sea ◽  
Co2 Injection ◽  
Gas Field ◽  
Southern North Sea

The Victor Field, Blocks 49/17, 49/22, UK North Sea

1991 ◽  
Vol 14 (1) ◽  
pp. 503-508 ◽  
Author(s):  
Robert A. Lambert
Keyword(s):  
North Sea ◽  
Early Permian ◽  
Gas Field ◽  
Eastern Flank ◽  
Southern North Sea ◽  
Recoverable Reserves ◽  
Fault Block ◽  
Sandstone Formation

AbstractThe Victor gas field lies in the Southern North Sea Gas Province on the eastern flank of the Sole Pit Basin. The field straddles Blocks 49/17 and 49/22, and is situated approximately 140 km off the Lincolnshire coast. Victor was discovered in April 1972 and is operated by Conoco (UK) Ltd on behalf of BP, Mobil and Statoil. The structure is an elongated tilted fault block, trending NW-SE. The reservoir sands are contained in the Leman Sandstone Formation (Rotliegendes Group) of Early Permian age, and consist mainly of stacked aeolian and fluvial sands with a gross thickness of 400-450 ft across the field. Porosities vary from 16-20%, with permeabilities ranging from 10 md to 1000 md in the producing zones. Initial gas in place is estimated at about 1.1 TCF with recoverable reserves of the order of 900 BCF. The field was brought on-stream in October 1984, and the five producing wells deliver, on average, 200 MMSCFD through the Viking Field 'B Complex' to the Conoco/BP terminal at Theddlethorpe in Lincolnshire

Ravenspurn South Field, Blocks 42/29, 42/30, 43/26, UK North Sea

1991 ◽  
Vol 14 (1) ◽  
pp. 469-475 ◽  
Author(s):  
R. D. Heinrich
Keyword(s):  
North Sea ◽  
Reservoir Quality ◽  
Desert Environment ◽  
Gas Field ◽  
Field Development ◽  
Southern North Sea ◽  
Fluvial Processes ◽  
Sandstone Formation ◽  
Aeolian Sands

AbstractThe Ravenspurn South Gas Field is located in the Sole Pit Basin of the Southern North Sea in UKCS Block 42/30, extending into Blocks 42/29 and 43/26. The gas is trapped in sandstones of the Permian Lower Leman Sandstone Formation, which was deposited by aeolian and fluvial processes in a desert environment. Reservoir quality is poor, and variations are mostly facies-controlled. The best reservoir quality occurs in aeolian sands wth porosities of up to 23% and permeabilities up to 90 md. The trap is a NW-SE-striking faulted anticline: top seal is provided by the Silverpit Shales directly overlying the reservoir, and by Zechstein halites. Field development began early in 1988 and first gas was delivered in October 1989. Production is in tandem with the Cleeton Field, about 5 miles southwest of Ravenspurn South, as the Villages project. Initial reserves are 700 BCF and field life is expected to be 20 years.

The Guinevere Field, Block 48/17b, UK North Sea

2003 ◽  
Vol 20 (1) ◽  
pp. 723-730 ◽  
Author(s):  
M. Lappin ◽  
D. J. Hendry ◽  
I. A. Saikia
Keyword(s):  
Fault Zone ◽  
North Sea ◽  
Production System ◽  
Early Permian ◽  
Gas Field ◽  
East Anglia ◽  
Southern North Sea ◽  
Fault Block ◽  
Sandstone Formation ◽  
The Uk

AbstractThe Guinevere Gas Field was discovered in January 1988 by the Mobil-operated well 48/17b-5. The field lies in the UK Sector of the Southern North Sea and occupies Block 48/17b. The field is located within the footwall of the Dowsing Fault Zone on the western flank of the Sole Pit Basin. Guinevere is a compressional northwesterly-trending fault block that comprises Early Permian Leman Sandstone Formation (Rotliegend Group) reservoir, sourced from the Carboniferous below and sealed by Later Permian Zechstein evaporates above.The Guinevere Gas Field is estimated to contain 90 BCF of recoverable gas reserves and was brought on-stream in June 1993 using a single not-normally-manned minimum facilities platform. Field life is predicted to be 13 years. Gas and condensate are evacuated though the Lancelot Area Production System (LAPS) to the onshore Bacton gas terminal in East Anglia.

The Windermere Gas Field, Blocks 49/9b, 49/4a, UK Southern North Sea

2003 ◽  
Vol 20 (1) ◽  
pp. 893-901
Author(s):  
R. J. Bailey ◽  
J. E. Clever
Keyword(s):  
North Sea ◽  
Central Area ◽  
Gas Field ◽  
Southern North Sea ◽  
Well Development ◽  
Coal Measures

AbstractThe Windermere Field, in the central area of the Southern North Sea gas province, exploits a variant of the Rotliegend-Leman Sandstone gas play. A thin, basal aeolian sandstone is top-sealed by lacustrine Silverpit Formation, clay stones and sourced by the underlying Westphalian Coal Measures. Since the reservoir unit has no mappable seismic expression, trap definition depends on depth mapping the Base Zechstein and adding the appropriate Silverpit Formation isochore. The trap is a simple, uncompartmentalized, anticlinal feature, lying largely within Block 49/9b. The 49/9b-2 discovery well (1989) penetrated the crest of the feature and the 49/9b-4 appraisal well (1994-1995) was drilled down-plunge to the SE. Both encountered some 20 m of predominantly aeolian-dune sandstone overlying the Base Permian Unconformity. This reservoir flowed dry gas at rates of 0.8-1.0 MMm3/d. The GWC was not penetrated; however RFT pressure projections suggest that it lies at around 3528 m. Stochastic estimates suggested Leman Sandstone GIIP of 2.8 bcm (104 BCF). The field's two-well development is tied back to a minimum facilities platform with export to Den Helder, via the Markham ST-1 platform. On commissioning, in August 1997, the two-wells flowed at 1.8 MMm3/day. By January 1999, 0.682 bcm of the originally-estimated 2.3 bcm gas reserve had been produced.

Problems Experienced During and After Installation of Gas Compression in UK Southern North Sea

1983 ◽  
Author(s):  
A. D. Simnett
Keyword(s):  
North Sea ◽  
Transmission System ◽  
Gas Field ◽  
Southern North Sea ◽  
Gas Compression ◽  
Series Configuration ◽  
The Uk

This paper relates the problems encountered with the operation of series configuration gas compression since its introduction in 1976 to the Leman Gas Field in the UK Southern North Sea gas transmission system. Various topics are addressed with the problem described and the adopted solution. Although solutions to these problems can be achieved by different methods, it is hoped that by relating these experiences, future operators embarking on offshore compression can take account during design stages and hence dispel the need of expensive modifications to plant offshore.

The Johnston Gas Field, Blocks 43/26a, 43/27a, UK Southern North Sea

2003 ◽  
Vol 20 (1) ◽  
pp. 749-759 ◽  
Author(s):  
David E. Lawton ◽  
Paul P. Roberson
Keyword(s):  
North Sea ◽  
Development Plan ◽  
Seismic Survey ◽  
3D Seismic ◽  
Seismic Attribute ◽  
Gas Field ◽  
Southern North Sea ◽  
North East ◽  
The North ◽  
The Uk

abstractThe Johnston Field is a dry gas accumulation located within blocks 43/26a and 43/27a of the UK Southern North Sea. The discovery well was drilled in 1990 and after the drilling of one appraisal well in 1991, a development plan was submitted and approved in 1993. Initially two development wells were drilled from a four slot sub-sea template, with commercial production commencing in October 1994. A further horizontal development well was added to the field in 1997.The field has a structural trap, fault bounded to the SW and dip-closed to the north, east and south. This field geometry has been established using high quality 3D seismic data, enhanced by seismic attribute analysis. The sandstone reservoir interval consists of the Early Permian, Lower Leman Sandstone Formation of the Upper Rotliegend Group. This reservoir consists of a series of interbedded aeolian dune, fluvial, and clastic sabkha lithofacies. The quality of the reservoir is variable and is principally controlled by the distribution of the various lithofacies. The top seal and fault bounding side seal are provided by the overlying clay stone of the Silverpit Shale Formation and the evaporite dominated Zechstein Supergroup.The field has been developed using a phased development plan, with the acquisition of a 3D seismic survey allowing for the optimized drilling of a high deliverability horizontal well.Current mapped gas initially-in-place estimates for the field are between 360 and 403 BCF, with an estimated recovery factor of between 60 and 75%.

Unlocking Small Gas Field Development In The Southern North Sea With The Application Of Modern Seismic Imaging Technologies

2013 ◽  
Author(s):  
Mathieu Darnet ◽  
Peter Van Loevezijn ◽  
Frans Hollman ◽  
Rob Wervelman ◽  
Matthias Bruehl ◽  
...  
Keyword(s):  
North Sea ◽  
Seismic Imaging ◽  
Gas Field ◽  
Imaging Technologies ◽  
Field Development ◽  
Southern North Sea
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