The Mercury and Neptune Fields, Blocks 47/9b, 47/4b, 47/5a, 42/29, UK North Sea

2003 ◽  
Vol 20 (1) ◽  
pp. 777-787
Author(s):  
B. Smith ◽  
V. Starcher
Keyword(s):  
North Sea ◽  
Reservoir Level ◽  
Southern North Sea ◽  
Export Rate ◽  
Recoverable Reserves ◽  
Closed Structure ◽  
Sandstone Formation ◽  
Gas Fields

AbstractThe Mercury and Neptune Gas Fields, discovered in 1983 and 1985 respectively, are located on the NW margin of the southern North Sea. Both fields have reservoirs in the Permian Lower Leman Sandstone Formation of the Rotliegend Group. The Mercury Field, at Rotliegend level, is an elongate, southerly tilting horst block. It trends NW-SE and is bounded by reverse faults. The Neptune Field, at top reservoir level is a faulted, four-way dip closed structure that is elongated in a NW-SE direction. The combined gas-in-place for the two fields is estimated at 465 BCF with recoverable reserves of 368 BCF. Development drilling on Mercury commenced in early 1999 and on Neptune it is scheduled to start in Q3 1999. The maximum gas export rate will be 250 MMSCFD with first gas anticipated in November 1999.

The Camelot Fields, Blocks 53/1a, 53/2, UK North Sea

1991 ◽  
Vol 14 (1) ◽  
pp. 401-408
Author(s):  
A. J. Holmes
Keyword(s):  
Phase I ◽  
Phase Ii ◽  
North Sea ◽  
Lower Permian ◽  
Southern North Sea ◽  
Recoverable Reserves ◽  
Sandstone Formation ◽  
Two Phases ◽  
Gas Fields ◽  
Central South

AbstractThe Camelot Gas Fields (Camelot North, Northeast and Central-South) lie in Blocks 53/la and 53/2 in the Southern North Sea, some 30 miles (48 km) east of Great Yarmouth. Initial sub commercial discovery wells were drilled in 1967, 1969 and 1972. Further exploration and appraisal drilling was carried out in 1987 and 1988. This paper covers the Field history up to the 53/la-10 appraisal well in June 1988. The Lower Permian, Leman Sandstone Formation is the reservoir, with the gas accumulations trapped in tilted fault terraces. The Leman Sandstone Fm. in the Camelot area is 800 ft thick with a gas column up to 200 ft. Development of the fields will be in two phases. Phase I will consist of 5 wells deviated from the Camelot 'CA' platform to produce reserves from the Camelot North and Central-South Fields. Production commenced in October 1989. Phase II scheduled for 1991/92 will tie-in the Camelot Northeast Field. Gas is exported from the unmanned 'CA' gathering platform via pipeline to Amoco's Leman 'A' complex, from where the gas is transported to shore via the existing Amoco pipeline from Leman to Bacton. Total recoverable reserves for the Camelot Fields are estimated at 215 BCF.

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

The Gawain Field, Blocks 49/24, 49/29a, UK North Sea

2003 ◽  
Vol 20 (1) ◽  
pp. 713-722
Author(s):  
R. A. Osbon ◽  
O. C. Werngren ◽  
A. Kyei ◽  
D. Manley ◽  
J. Six
Keyword(s):  
North Sea ◽  
Early Permian ◽  
Water Contact ◽  
Field Development ◽  
Dune Sands ◽  
Southern North Sea ◽  
Recoverable Reserves ◽  
Structural Relief ◽  
Sandstone Formation

AbstractThe Gawain Field is located on the Inde shelf in the Southern North Sea, 85 km NE of the Norfolk coast. Gawain was discovered in 1970 by well 49/29-1 and a total of nine wells have been drilled on the structure. Gas is produced from the Leman Sandstone Formation of Early Permian age. The reservoir section is comprised predominantly of stacked aeolian dune sands possessing excellent poroperm characteristics. The structure is a complex NW-SE trending horst block with a common gas-water contact at 8904 ft TVDss. Low structural relief has presented a major challenge to field development, which has utilized extended reach wells to maximize drainage potential. Initial gas-in-place is estimated at 289 BCF with recoverable reserves in the order of 196 BCF. The field came on production in September 1995 via a sub-sea tie back to the Thames infrastructure and has an expected field life of 10 years

The Sean North and Sean South Fields, Block 49/25a, UK North Sea

1991 ◽  
Vol 14 (1) ◽  
pp. 485-490 ◽  
Keyword(s):  
North Sea ◽  
Material Balance ◽  
The Other ◽  
Peak Shaving ◽  
Southern North Sea ◽  
Recoverable Reserves ◽  
Cap Rock ◽  
Sandstone Reservoir ◽  
Gas Fields

AbstractSean North and Sean South are two small prolific gas fields located on the Indefatigable Shelf in the Southern North Sea. They, like most of the other fields in the area, have a Carboniferous source, a Rotliegend aeolian sandstone reservoir and a Zechstein evaporite cap rock. They have been developed to fullfil a peak-shaving role, being produced for only a few days per year in times of high gas demand when they produce at a rate of 600 MMSCFD. Initially thought to be two equally sized accumulations, there is now some evidence from material balance calculations that the Sean South is bigger than North Sean. The contractual recoverable reserves for the two fields are 425 BCF.

The Clipper Field, Blocks 48/19a, 48/19c, UK North Sea

2003 ◽  
Vol 20 (1) ◽  
pp. 691-698
Author(s):  
M. J. Sarginson
Keyword(s):  
North Sea ◽  
Upper Permian ◽  
Lower Permian ◽  
Reservoir Properties ◽  
Gas Field ◽  
Field Development ◽  
Matrix Permeability ◽  
Recoverable Reserves ◽  
Reservoir Permeability ◽  
Sandstone Formation

AbstractThe Clipper Gas Field is a moderate-sized faulted anticlinal trap located in Blocks 48/19a, 48/19c and 48/20a within the Sole Pit area of the southern North Sea Gas Basin. The reservoir is formed by the Lower Permian Leman Sandstone Formation, lying between truncated Westphalian Coal Measures and the Upper Permian evaporitic Zechstein Group which form source and seal respectively. Reservoir permeability is very low, mainly as a result of compaction and diagenesis which accompanied deep burial of the Sole Pit Trough, a sub basin within the main gas basin. The Leman Sandstone Formation is on average about 715 ft thick, laterally heterogeneous and zoned vertically with the best reservoir properties located in the middle of the formation. Porosity is fair with a field average of 11.1%. Matrix permeability, however, is less than one millidarcy on average. Well productivity depends on intersecting open natural fractures or permeable streaks within aeolian dune slipface sandstones. Field development started in 1988. 24 development wells have been drilled to date. Expected recoverable reserves are 753 BCF.

The Amethyst Field, Blocks 47/8a, 47/9a, 47/13a, 47/14a, 47,15a, UK North Sea

1991 ◽  
Vol 14 (1) ◽  
pp. 387-393 ◽  
Author(s):  
C. R. Garland
Keyword(s):  
North Sea ◽  
Reservoir Quality ◽  
Geological Model ◽  
Gas Field ◽  
Seismic Parameters ◽  
Recoverable Reserves ◽  
High Production ◽  
Sandstone Formation ◽  
Phased Development ◽  
Overlying Strata

AbstractThe Amethyst gas field was discovered in 1970 by well 47/13-1. Subsequently it was appraised and delineated by 17 wells. It consists of at least five accumulations with modest vertical relief, the reservoir being thin aeolian and fluviatile sandstones of the Lower Leman Sandstone Formation. Reservoir quality varies from poor to good, high production rates being attained from the aeolian sandstones. Seismic interpretation has involved, in addition to conventional methods, the mapping of several seismic parameters, and a geological model for the velocity distribution in overlying strata.Gas in place is currently estimated at 1100 BCF, with recoverable reserves of 844 BCF. The phased development plan envisages 20 development wells drilled from four platforms, and first gas from the 'A' platforms was delivered in October 1990. A unitization agreement is in force between the nine partners, with a technical redetermination of equity scheduled to commence in 1991.

The Hewett Field, Blocks 48/28a, 48/29a, 48/30a, 52/4a and 52/5a, UK North Sea

2020 ◽  
Vol 52 (1) ◽  
pp. 189-202 ◽  
Author(s):  
J. A. Hook
Keyword(s):  
Fault Zone ◽  
North Sea ◽  
Structural Evolution ◽  
Field Development ◽  
Southern North Sea ◽  
Sandstone Formation ◽  
The Uk ◽  
Basin Margin ◽  
Sour Gas

AbstractThe Hewett Field has been in production for some 50 years. Unusually for a Southern North Sea field in the UK Sector, there has been production from several different reservoirs and almost entirely from intervals younger than the principal Leman Sandstone Formation (LSF) reservoir in the basin. Some of these reservoirs are particular to the Hewett area. This reflects the location of the field at the basin margin bound by the Dowsing Fault Zone, which has influenced structural evolution, deposition and the migration of hydrocarbons. The principal reservoirs are the Permo-Triassic Hewett Sandstone (Lower Bunter), Triassic Bunter Sandstone Formation (BSF) (Upper Bunter) and Permian Zechsteinkalk Formation. There has also been minor production from the Permian Plattendolomit Formation and the LSF. Sour gas is present in the BSF only. Several phases of field development are recognized, ultimately comprising three wellhead platforms with production from 35 wells. Gas is exported onshore to Bacton, where the sour gas was also processed. Peak production was in 1976 and c. 3.5 tcf of gas has been recovered. Hewett has also provided the hub for six satellite fields which have produced a further 0.9 tcf of gas. It is expected that the asset will cease production in 2020.

The Ivanhoe and Rob Roy Fields, Blocks 15/21a-b, UK North Sea

1991 ◽  
Vol 14 (1) ◽  
pp. 331-338 ◽  
Author(s):  
R. H. Parker
Keyword(s):  
North Sea ◽  
Upper Jurassic ◽  
Rock Properties ◽  
Production Facility ◽  
Injection Wells ◽  
Recoverable Reserves ◽  
Fault Block ◽  
Moray Firth ◽  
Sandstone Formation ◽  
Northeast Coast

AbstractThe Ivanhoe and Rob Roy Fields are located in the Outer Moray Firth Basin, seventy nautical miles off the northeast coast of Scotland. The Ivanhoe Field was discovered in 1975, and the Rob Roy Field in 1984. The reserves in both fields occur in tilted fault block traps of Upper Jurassic, Piper Sandstone Formation. Estimated total recoverable reserves amount to 100 MMBBL and 62 BCF. The fields are separated by a water corridor approximately 1 km wide. Both fields contain two reservoir sandstone units, an upper and lower, locally termed the Supra Piper Sandstone and Main Piper Sandstone respectively. The reservoirs in both fields exhibit excellent rock' properties with porosities up to 28% and permeabilities of several Darcies.Each field is developed via a subsea manifold surrounded by a cluster of production and injection wells, of which two were pre-drilled on Ivanhoe and six pre-drilled on Rob Roy. This allowed rapid achievement of the 60 000 BOPD plateau oil production rate soon after commissioning of facilities in July 1989. The two subsea manifolds are tied into a single subsea production manifold which connects with a Floating Production Facility. Crude oil is exported to the Claymore A Platform and gas to the Tartan A Platform.

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