Everest gasfield

The Everest gasfield is located in the Central North Sea, 233 km east of Aberdeen, Scotland. It lies in the United Kingdom Continental Shelf blocks 22/9, 22/10a and 22/14a. The gasfield was discovered by Amoco in 1982 with first gas produced in 1993.[1]

Ownership

Until 2009, the field was operated by BP (formerly Amoco). As a result of assets' swap between BP and BG Group in 2009, BG Group became the largest stakeholder of field with 80.46% interest and it took over operatorship of the field.[2] Other partners beside of BG Group are Amerada Hess, and Total. The 1.0134% interest, which was owned by ConocoPhillips, was acquired by BG Group in 2007.[3]

Operations

Everest well fluids are routed to the vertical HP (High Pressure) Separator where condensate is separated from the gas stream.[6] Wells may also be routed to the vertical test separator where 3-phase (Gas/Condensate/Water) separation and measurement of each stream takes place. Gas from the HP Separator (and the Test Separator) is cooled by cooling medium and flows to the vertical TEG Contactor Scrubber where condensate is recovered. The gas is heated with heating medium prior entering the base of the TEG Contactor where it is in counter-current contact with triethylene glycol.[6] The dried gas flows to the Dense Phase Suction Scrubber where any recovered liquids are removed. A side stream of fuel gas for the installation is taken from the Dense Phase Separator. The main gas stream is compressed in the Dense Phase Compressor to c. 140 bar. The gas is metered prior to export across the bridge to the CATS Riser platform and through the CATS pipeline. In later field life, as well pressures declines, further lower pressure compressors were installed between the HP Separator and the TEG Contactor Scrubber.[6] The gas compression capacity is 135 e6ft3/d at standard pressure.[5]

Condensate from the HP Separator and the Test Separator is routed to the horizontal IP (Intermediate Pressure) Separator where 3-phase separation takes place.[6] Vapour is routed to the MP Vapour Recovery Compressor and thence to the TEG Contactor Scrubber. Separated water is routed to the Produced water system for oil removal prior to overboard disposal. The produced water system has a capacity of 5000 oilbbl per day.[5] Condensate from the IP Separator is heated and routed to the LP (Low Pressure) Separator where further 3-phase separation takes place. Vapour is cooled with cooling medium and flows to the LP Vapour Recovery Suction Scrubber where further condensate is removed. Vapour from the LP Vapour Recovery Suction Scrubber is compressed in the LP Vapour Recovery Compressor and after cooling is routed to the MP Vapour Recovery Compressor. Condensate from the LP Separator is cooled and routed to the Condensate Surge Drum. From the Surge Drum condensate is metered and exported to the Forties Field via the Pipeline Pumps.[6] The condensate export capacity is 10,000 oilbbl per day.[5]

location map	North Sea
coordinates	57.75°N, 1.801°W
relief	yes
country	Scotland, United Kingdom
region	Central North Sea
blocks	22/9, 22/10a and 22/14a
offonshore	offshore
operator	Chrysaor
partners	100% equity
discovery	1982
start development	1991
start production	1993
peak year	2000
oil production bbl/d	10000
production gas mmcuft/d	135
est gas bft	770
formations	Palaeocene Forties sandstone, Paleocene Andrew sandstone

Ownership

Infrastructure

Operations

See also

External links

References