The Beryl oil field is a major crude oil production field in the UK sector of the northern North Sea, 335 km north east of Aberdeen, Scotland. Production of oil started in 1976 and the field is still producing oil and gas (2021).
The field The Beryl oil field is located in Block 9/13a of the UK North Sea. It is named after Beryl Solomon wife of Charles Solomon the President of Mobil Europe at the time of the field’s discovery. The Beryl field was discovered in May 1972 and is a Triassic and Jurassic sandstone at an average depth of 11,000 feet (3,353 m). The reservoir and the fluids have the following characteristics: +Beryl reservoirsReservoirPorosity %Permeability mdWater saturation %Net/Gross ratio %Bruce141001068Upper Beryl17300890Middle Beryl151001242Lower Beryl151001280Lewis15203050 +Beryl reservoir fluidsParameterValueAPI gravity36.5°APIGas Oil Ratio1,300 standard cubic feet/barrelSulfur content0.3 %Recoverable reserves Beryl A500 million barrelsRecoverable reserves Beryl B300 million barrelsRecoverable gas1.6 trillion cubic feet
Owners and operators The Beryl field was originally licensed to partners comprising Mobil North Sea Ltd (50%), Amerada Hess (UK) Ltd (20%), Texas Eastern North Sea Inc. (20%), and Enterprise Oil Ltd. (10%). Mobil was the Beryl field operator. In January 2012 the Apache Corporation acquired all the assets of Mobil North Sea and from then was the operator of the Beryl field with a 50% interest. The other owners are Hess Limited (22.22%), Enterprise Oil (22.78%) and OMV (UK) Ltd (5%).
Development The field was initially developed in 1975 by a single integrated drilling, production and accommodation platform Beryl Alpha (or Beryl A) located in the south of the field. Beryl A has oil storage compartments in the gravity base structure. Oil is exported from Beryl A through a pair of SPM (single point mooring) buoys located 2.0 km from Beryl A. Beryl Bravo (Beryl B) was installed in 1983 and located 8 km north of Beryl A to exploit the northern part of the oil field. Oil is exported from Beryl B to Beryl A through a 20-inch pipeline.
As a ‘stranded asset’ with limited infrastructure gas was injected into the reservoir and the surplus was flared. From 1992 gas was exported via the 203 miles (327 km) 30-inch SAGE (Scottish Area Gas Evacuation) pipeline to St. Fergus. In 1990 a riser tower was added to Beryl A to accommodate risers and gas compression equipment to export gas into SAGE. The principal data of the Beryl field platforms is given in the following table. +Beryl field platformsInstallationBeryl ABeryl BBeryl Riser Access Tower (RAT)Coordinates59°32’47”N 01°32’14”E59.610342N 1.512742E59.545178N 1.535725EWater depth, metres117120117Fabrication substructureNorwegian Contractors StavangerRGC MethilFabrication topsides Aker ArendalBechtel Middlesbrough & CherbourgTopside weight, tonnes28,00034,300FunctionDrilling, production, storage, accommodationDrilling, production, accommodationRisers, compressionAccommodation290200–TypeCondeepSteel jacketSteel jacketLegs384Substructure 19 concrete fuel cells32 skirt pilesWell slots4021NilThroughput oil, bpd300,000 (including B)100,000–Throughput gas, MMSCFD150137–Oil storage capacity, barrels900,000NilNilGas injection, million m3/day4.03.7–Water injection100,000 bwdNilNilInstalledJuly 1975May 19831990Production startJune 1976July 19841990Oil production toSPM buoysBeryl ABeryl AGas production toFlare, RATSAGESAGE The Beryl partners had sanctioned the construction of Beryl B on the understanding that uplift on allowances against Petroleum Revenue Tax would be available for the expenditure. But the UK Government intended to restrict the uplift. Mobil, on behalf of the Beryl partners, argued that if it had been known that uplift was to be withdrawn the investment in Beryl B would not have been made.
Export of oil from the field was by SPM buoys, the design details of the buoys was as follows. +Beryl SPM loading buoysSPM A (SPM1)SPM B (SPM2)Coordinates59.554322 1.56266759.534403 1.559217TypeArticulated lattice towerArticulated cylindrical towerWater depth, metres119120Supply from32-inch pipeline from Beryl A32-inch pipeline from Beryl ACapacity, barrels/h40,00040,000Loading hose16-inch16-inchHeight, metres149166Weight, tonnes1,2002,415FabricationCFEMACMP, MarseilleInstallationSeptember 1975September 1982 In 1985 SPM1 broke free from its moorings and was damaged beyond repair. A replacement, SPM3, was installed in 1987.
An emergency flare is bridge-linked to Beryl A. This comprises a 600 feet (183 m) horizontal steel bridge. The bridge is supported by a 410 feet (125 m) high steel tower with a concrete gravity base.
Production Beryl A was planned to have 30 production wells and 10 gas or water injection wells.
The processing plant on Beryl A had a nominal capacity of 300,000 barrels of oil per day. There are two parallel process trains each capable of processing 150,000 bbl/day. Oil from the wellheads flows to one of the two High Pressure Separators operating at 150 psi where gas flashes off. Oil then passes to the Low Pressure Separator operating at 3 psi for further gas removal. From here oil flows to the storage tanks prior to export via the SPM buoys. Off-gas from the LP separators is compressed to 150 psi in a centrifugal compressor capable of compressing 12 MMSCFD. The compressed gas is mixed with off-gas from the HP Separator the combined flow of 150 MMSCFD is compressed in 2 stages to 5,200 psi and is injected into the reservoir. Gas injection started in November 1977.
Deoxygenated seawater was injected into the reservoir at up to 100,000 barrels per day, this commenced in January 1979.
Beryl B was planned to have 14 production wells, 5 water injection and 2 gas injection wells.
Processing plant comprised a single 3-phase Separator and an electric motor driven gas compressor.
Redevelopment Further fields in the Beryl area were developed through Beryl A and B.
From 1979 oil was produced from three subsea satellite wells. These were connected to Beryl A by 6-inch flowlines. +Beryl subsea wells Well9/13a-6A9/13a-159/13a-20BDistance3.35 km7.01 km4.57 kmInstallationNovember 1978January 1979September 1979First productionEnd 1979End 1979End 1979 Further developments included production from small oil and gas fields in the Beryl area. Information on these fields is summarized in the table. Nevis, Ness and Linnhe are named after Scottish lochs. +Beryl area satellite fieldsFieldNevis SouthNevis North, Central, WestNessBucklandSkeneLinnheBlock9/139/139/13b9/189/199/13Discovery1986199920011988Recoverable reserves, million tonnes5.4Oil gravity, °API37 –Water depth, metres108113120118123Production start1996, now ceased1988199920011989, ceased 1991Production rate1.0 million tonnes/year30,000 bbl/d180 MMSCFDProduction toBeryl ABeryl BBeryl BBeryl ABeryl ABeryl B
Decommissioning Nevis South and Linnhe subsea installations have been decommissioned.
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