| Anglia gas field | |
| Location Map: | North Sea |
| Coordinates: | 53.3333°N 1.5833°W |
| Country: | United Kingdom |
| Location: | Southern North Sea |
| Blocks: | 48/18b, 48/19b, 48/19e |
| Offonshore: | offshore |
| Operator: | Ithaca Energy |
| Partners: | Ithaca Energy (30%) First Oil (32.8%) Dana Petroleum 25% DEA AG (12.2%) |
| Discovery: | February 1972 |
| Start Production: | 1991 |
| Abandonment: | November 2015 |
| Est Gas Bft: | 235 |
The Anglia gas field, is a natural gas field in the United Kingdom's continental shelf of the Southern North Sea. It is located in blocks 48/18 and 48/19 about 60 km (37 mi) east of the Lincolnshire coast. The reservoir is located at a depth of approximately subsea. The field was discovered in February 1972. Detailed seismic and appraisal well work were conducted in 1984.[1] The reservoir was estimated to have 235 billion cubic feet of gas in place.
The original partners were Ranger Oil (operator, 35.628%), Conoco (31.25%), Elf Oil and Gas (16.46%), Amerada Hess (12.83%), and Triton Resources (3.832%).[2] In December 2010, Ithaca Energy became operator of the Anglia field by acquiring 30% stake in the field from GDF Suez E&P UK.[3] Other partners are First Oil (32.8%), Dana Petroleum 25%, and DEA AG (12.2%).[4]
The field, at a cost of $120 million, was initially developed in 1991 through the Anglia A Normally Unattended Installation (NUI). The NUI had five producing wells including, at that time, the longest horizontal well drilled in British waters: the A3Z well has a 3,568 ft horizontal section. Production was through a 12-inch diameter pipeline to the Conoco (later ConocoPhillips) operated LOGGS (Lincolnshire Offshore Gas Gathering System) complex and thence to Theddlethorpe gas terminal. In 1993 the field was further development through the Anglia YM subsea template, with fluids produced via an 8-inch pipeline to Anglia A.
The design parameters of the Anglia production facilities are summarised in the table.[5]
| Block | 48/18b, 48/19b | 48/18b | |
| Coordinates | 53° 22.057’N 1° 39.100’E | 53⁰ 22.322’N 10° 34.752’E | |
| Installation type | Fixed steel platform | Subsea wellheads | |
| Installed | 1991 | 1993 | |
| Water depth, metres | 22.5 | 31 | |
| Substructure weight, tonnes | 1,008 | ||
| Topsides weight, tonnes | 870 | – | |
| No. of legs | 3 | – | |
| No. of Wells | 6 | 2 | |
| Gas export to | LOGGS PP | Anglia A | |
| Export pipeline length, diameter | 23.7 km, 12-inch | 4.9 km, 8-inch | |
| Pipeline number (gas) | PL854 | PL954 | |
| Methanol import from | LOGGS PP | Anglia A | |
| Methanol pipeline length, diameter | 23.7 km, 3-inch | 4.9 km, 6-inch | |
| Pipeline number (methanol) | PL855 | PL955 |
Fluids from the individual wells were routed to the Production Manifold. From the manifold fluid flowed to a Demister which removed solids and liquids, the gas passed directly to export. Water, sand and condensate from the Demister passed to the 2-phase Inlet Separator with sand routed to the Sand Accumulator which was periodically dumped to a caisson. The liquids from the Sand Accumulator were routed to a Hydrocyclone. Separated condensate was combined with the gas stream and flowed to export. Water from the hydrocyclone flowed to a Degasser and was discharged overboard. Anglia was also provided with a 3-phase Test Separator where individual wells could be tested.[6]
A summary of the key gas production data for the Anglia field is shown on the table.[7]
| Anglia | ||
| Start of production | 1991 | |
| Peak flow, million cubic metres/y | 547 | |
| Year of peak flow | 1992 | |
| Cumulative production to end of 2014, million cubic metres | 5,703 | |
| Production ceased | 2016 |