CERES & ERIS
Eris and Ceres are single well subsea tiebacks, located approximately 34km and 44km respectively east of the Easington Gas Terminal in the Southern North Sea. Eris sits in block 47/8c-4 at a water depth of 41m and Ceres in 47/9c-11 in a water depth of 29m.
Both export through the Mercury subsea manifold, and then flow via Neptune and onwards to Cleeton and the Dimlington onshore terminal. Production commenced in 2010, with an expected field life of the mid 2020s.
The Morecambe Hub comprises three fields in the East Irish Sea - North Morecambe, South Morecambe and Rhyl. The fields lie approximately 25km south west of Walney Island, across blocks 110/2a, 110/3a, 110/8a and 113/27b, in water depths that range from 17 to 35m.
One of the largest gas fields in the UKCS, at its peak, the Morecambe Hub met 20% of the UK’s domestic gas demand. Despite being in production for over 30 years, the Morecambe Hub remains a cornerstone operated asset in the Spirit Energy portfolio with production expected into the mid-2020s.
South Morecambe was discovered in 1974 and was the first to be developed, with production starting in 1985. The field has been developed using seven fixed jacket platforms, including the three-platform manned Central Processing Complex (CPC), four Normally Unmanned Installations (NUIs) and 36 development wells. Gas is exported via a 36” dedicated pipeline to the Barrow Gas Terminals. North Morecambe was discovered in 1976, with first gas in 1994. The development includes the normally unmanned DPPA platform which acts as the main gathering hub for the area, 10 development wells and a 12” pipeline to the Barrow Gas Terminals. Rhyl, which is north of the North Morecambe field, was discovered in 2009 and brought into production in March 2013. It has been developed as a two-well subsea tieback to DPPA.
Gas from all the fields is processed at Barrow Gas Terminals, which is located near Barrow-in-Furness in Cumbria, before entry into the National Transmission System. Spirit Energy’s offshore facilities and onshore terminal also provides gathering and processing services for third parties.
Seven Seas is a single well subsea tie back which sits in block 48/7c in the Southern North Sea, approximately 60km from the East Yorkshire coast, in a water depth of 34m. Gas from the field is exported via an 8” pipeline, via the Newsham wellhead and onwards to West Sole Alpha, where a 16” gas export pipeline runs to the Dimlington onshore terminal.
Production commenced in 2012. A side-track opportunity is under review to determine if the field life can be extended from 2021 to the late 2020s.
Located in blocks 16/12a and 16/7 in the Central North Sea, in a water depth of 125m, Trees is a multi production and injection well subsea development over three separate oil accumulations (Birch, Larch and Sycamore), tied back to Brae Alpha. One Sycamore production well is an extended reach platform well from the Tiffany platform, and oil is exported via the Forties Pipeline. Production started in 1995, with an expected field life of 2023+.
The York field straddles blocks 47/2a, 47/3a, 47/3d and 47/3e in the Southern North Sea, in a water depth of 42m, approximately 34km from the North East Yorkshire coastline. The York facility is a Not Permanently Attended Installation (NPAI). The platform is a four-legged, jacket-type fixed installation, with three platform wells in production.
Well fluids are gathered in a manifold and exported to the Easington Gas Terminal via a 16" export line. The platform, which was installed in 2012 (with a 25-year design life) is also controlled remotely from Easington. Production commenced in 2013 and options for extending the life of York are ongoing, with a target end of field life ~2022.
The Alba field lies about 130 miles northeast of Aberdeen in the Central North Sea, in block 16/26, in a water depth of approximately 138 metres.
Discovered in 1984, Alba is a heavy oil field and was one of the first shallow Eocene reservoirs to be successfully developed in the North Sea. First oil was achieved in January 1994, with an expected field life of 2030+.
The field’s facilities include the fixed jacket Alba North Platform (ANP), with a dry tree well bay, drilling package and three phase processing facilities. The field was further developed in 2001, through the addition of the Alba Extreme South (AXS) production and injection subsea development, tied back to the ANP, with oil exported to the Alba Floating Storage Unit (FSU) which is located in the field on a permanent basis.
The Brae Area lies approximately 170 miles north-east of Aberdeen, in a water depth of approximately 110m. Three fixed jacket platforms - Alpha, Bravo and East Brae - support the wider area which consists of North, South, East and West Brae; Beinn, Braemar and Kingfisher; with the Spirit Energy-operated Trees field and various third parties tied in.
Brae Alpha commenced production in 1983, Brae Bravo in 1988 and East Brae in 1993. The Central and West Brae/Sedgwick subsea tiebacks to Brae Alpha commenced production in 1989 and 1997 respectively, while the Braemar subsea tieback to East Brae commenced in 2003. Brae Bravo reached Cessation of Production (COP) in 2018 and is now hydrocarbon free and a permanently unattended installation. The topside and jacket removal is sanctioned for execution in 2021/22. East Brae is expected to reach cessation of production (COP) end-2021, with COP of Braemar expected end-2023. Brae Alpha has an expected field life of 2027.
Liquids from the Brae Area are exported via the Ineos-operated Forties Pipeline and gas is transported via the Scottish Area Gas Evacuation (SAGE) pipeline to St Fergus.
Clipper South is a tight gas field in blocks 48/19 and 48/20 in the Southern North Sea, approximately 100km east of the Lincolnshire coast, south of Galleon and Ensign, in a water depth of between 22m to 26m. Four long, horizontal, multi-fracced wells are produced to a Not Permanently Attended Installation (NPAI).
In 2018, a new pipeline, subsea infrastructure and processing equipment was installed to re-route production from the Clipper South field to the Clipper platform and onward to the Bacton Gas Terminal on the North Sea coast of North Norfolk. Clipper South is a relatively young asset, with significant remaining reserves and an estimated cessation of production (COP) date of 2028/29.
The Cygnus Field is located in the Southern North Sea in blocks 44/11a and 44/12a, approximately 12km north of the Munro Field and 15km northwest of the Tyne Field. Water depth in this location ranges from between 15 to 25 metres.
The Cygnus infrastructure consists of three bridge-linked Alpha platforms, including a wellhead drilling centre (AWHP), a processing/utilities unit (APU) and the living quarters/central control room (AQU). The Bravo wellhead platform, a Not Permanently Attended Installation (NPAI), is located approximately 7km northwest of Cygnus Alpha. Gas and condensate is exported from the Alpha PU platform to the Bacton Gas Terminal. In Bacton, Cygnus gas is blended with a high Wobbe Index gas to achieve National Grid entry specification.
First production from Cygnus was on 13 December 2016 (Alpha) and 1 August 2017 (Bravo), with the Greater Cygnus Area expected to provide economic production potential beyond 2030.
Davy East is a subsea well located in block 53/5b in the Southern North Sea, in a water depth of 41m. It lies 5km south-east of the Perenco-operated Davy platform, with its established export route to the Indefatigable Field and the Bacton Gas Terminal on the North Sea coast of North Norfolk. Well cycling from 2020 and no planned activity. The Davy COP will dictate the Davy East COP, currently estimated to be 2027.
Galleon is located in block 48/20 in the Southern North Sea, east of Clipper and west of Audrey (Sole Pit Area), in a water depth of 28m. It consists of 17 horizontal wells, of which 10 are currently in production and produced through two unmanned platforms - PN and PG, in ~45m water depth. The gas is exported via Clipper to the Bacton Gas Terminal on the North Sea coast of North Norfolk. First production was in 1994 and the asset has a long production profile with cessation of production (COP) expected in 2035.