Goldeneye Goldeneye
PRODUCTION FACILITY
Facility Name Goldeneye FSO Duty Gas
Operator Shell Current Status Abandoned since 2011
Host Type FSO/FSU Water Depth 122 m / 403 ft
Dev.Cost $401,000,000 Region UK
 
Location UKCS Blocks 14/29a, 20/4b, 20/3b
 
OIL & GAS FIELD
Field Name Goldeneye Discovery Date Jan 1996
Block UKCS Blocks 14/29a, 20/4b, 20/3b Reserve Type Gas
Current
Status
Abandoned (Ex-Producer) Production Start Jan 2004
Water Depth 122 m / 403 ft
 
 
Description
 
The Goldeneye offshore gas field spans UKCS Blocks 14/29a, 20/4b and 20/3b in a water depth of 400 feet (122 meters). Goldeneye is located 65 miles (105 kilometers) from Northeast Scotland in the South Halibut Basin area of the Outer Moray Firth.

With oil equivalent reaching 135 million barrels, Goldeneye has more than 500 billion cubic feet of gas reserves and 17 million barrels of gas condensate. The reservoir is located in the Lower Cretaceous Captain Sandstone.

The field is operated by Shell, which holds 49% interest; ExxonMobil holds 39%; Talisman holds 7.5%; and Centrica holds the remaining 4.5% interest.

Goldeneye was discovered in 1996, but was considered uneconomic due to its long distance from an existing infrastructure. Then in 2002, Shell decided to develop the field using an unmanned platform and extensive subsea pipeline system.

Field Development

Field development was approved by the UK authorities on January 18, 2002. The production consent lasts until the close of 2014.

In 2003, five production wells were drilled in 394 feet (120 meters) of water as an alternative to subsea completions. At the time, this was the deepest water depth in which a jackup rig was used for production drilling in the UK.

The project also entailed constructing an unattended wellhead offshore platform on UKCS Block 14/29b in 1,312 feet (400 meters) of water. The unit does not have any processing facilities aboard because all processing will take place onshore.

The jacket for the platform has a width of 115 feet (35 square meters), with a height of 459 feet (140 meters), and weighs 3,000 tons (2,722 tonnes). Aker Verdal AS, an affiliate of Kvarener Group, completed the engineering, procurement and construction of the jacket and piles at the Verdal yard in Norway. The jacket was delivered to its field location on June 2003.

Stratos provided communication on the unmanned platform. Two 4-foot (1.2-meter) Sea Tel stabilized Ku band systems were linked back to diverse locations on different satellites. The project consisted of two project firsts, in terms of Ku band services to a local major oil operator. First, a 12-foot (4-meter) antenna was installed at St. Fergus to provide the main link for data services to and from the installation. Second, the project used a Stratos Demand Assigned Multiple Access service for the second back-up link. Stratos also provided space segment, data equipment and a VSAT terminal onshore for the project.

Pipeline

Gas and condensate at reservoir pressure is transported from the unmanned platform to the National Transmission System at Transco in St. Fergus, where all processing takes place; from there, hydrocarbons are transported to the Fife Natural Gas Liquids plant in Mossmorran.

To transport the gas, a 63-mile (101-kilometer), 20-inch subsea pipeline was installed to transfer products from the unattended platform to the processing facility onshore. This pipeline is the longest tied-back full-well stream pipeline in the UK Continental Shelf.

To export Methanol and other chemicals from the plant to the platform, a 4-inch MEG service line was trenched and buried.

Saipem UK Ltd. constructed both pipelines and welded them together. They were then laid by pipelay vessel Castoro Sei.

Halliburton provided the pre-commissioning work on the two pipelines. The scope of work included flooding, cleaning, gauging, high pressure flushing, and hydro testing the pipelines onshore to enable them to transport gas and condensate from the field to Shell's onshore gas plant.

Production

The field came online in 2004, and provided 3% of natural gas for the United Kingdom. This was the first time that gas was brought onshore from the Outer Moray Firth area.

The field produced more than 100 MMcf/d (2.8 MMcm/d), and more than 10,000 barrels of gas condensate a day. Goldeneye ceased production in March 2011. Either the field will be used as a CO2 storage facility or it will be decommissioned. Shell is currently working with Petrofac subsidiary C02 DeepStore to decide the field's fate.




 
Activities
 
Field Development
Date: Jan. 2003
Type: Development Activity
In 2003, five production wells were drilled in 394 feet (120 meters) of water as an alternative to subsea completions. At the time, this was the deepest water depth in which a jackup rig was used for production drilling in the UK.
 
Status History
 
Goldeneye FSO

Abandoned - Mar 02, 2011 to -
Producing - 2004 to Mar 01, 2011
The unmanned platform commenced production in 2004.
Goldeneye

Abandoned (Ex-Producer) - Mar 02, 2011 to -
Goldeneye ceased production in March 2011. The field may be used as a C02 storage facility or decommissioned.
Producing - 2004 to Mar 2011
The field came online in 2004, and provides 3% of natural gas for the United Kingdom.
Under Development - 2002 to Dec 2003
In 2002, Shell decided to develop the field using an unmanned platform and extensive subsea pipeline system.
Discovery (Drilled) - 1996 to 1996
Goldeneye was discovered in 1996, but was considered uneconomic due to its long distance from existing infrastructure.
 
Project Map Europe - North Sea
Line Separator
Project Image
Goldeneye Platform in the North Sea
 
Installation of Goldeneye Topsides
 
Goldeneye Detail Map