Projects Database

Sleipner  CO2 Storage

PROPONENTS:

Capture, Transport and Storage: The Sleipner CO2 storage partners consist of Statoil (58.35 per cent and Operator), ExxonMobil E&P Norway (17.24 per cent), Lotos E&P Norway AS (15 per cent) and KUFPEC Norway AS (9.41 per cent).

LOCATION: Offshore Norway, Central North Sea

COcapture source: Natural gas from the Sleipner West field, via a processing facility on the Sleipner T platform, 240 kilometres / 149 miles west-southwest of Stavanger, offshore Norway

COstorage site: Utsira Formation, above the Sleipner East field, Central North Sea

INDUSTRY (FEEDSTOCK): Natural gas processing (natural gas)

OVERALL PROJECT LIFECYCLE STAGE: Operating

CO2 CAPTURE CAPACITY VOLUME: 1 million tonnes per annum (Mtpa)

CAPTURE TYPE: Industrial separation

CAPTURE METHOD: Absorption chemical solvent-based process (Amine)

NEW BUILD OR RETROFIT: New build

COCAPTURE START DATE: September 1996

PRIMARY STORAGE OPTION: Dedicated geological storage - offshore deep saline formation

STORAGE FORMATION AND DEPTH: Sandstone at a depth approximately 800-1,100 metres / 2,625-3,610 feet below sea level

TRANSPORTATION TYPE: No transport required (direct injection)

TRANSPORTATION DISTANCE TO STORAGE SITE: Not applicable


Facilities description

The Sleipner area gas development is located in the middle of the Central North Sea, near the border between the UK and Norway and approximately 240 km / 149 miles west-southwest of Stavanger, Norway. The development embraces the Sleipner East and Sleipner West gas and condensate fields (and tie-ins from a number of satellite fields). Sleipner East came on stream in 1993, Sleipner West in 1996. The two Sleipner fields have produced almost 2 billion barrels of oil equivalent since inception.

Sleipner West produces from the Middle Jurassic Sleipner and Hugin Formations, with most reserves found in the Hugin Formation. The reservoir depth is approximately 800-1,100 metres / 2,625-3,610 feet below sea level (water depth at Sleipner West is at 110 metres / 361 feet).

The COcontent of the gas stream in Sleipner East is within market specifications (less than 2.5 per cent). Sleipner West gas, however, has a CO2 content in the range of 4-9 per cent, which must be reduced to meet customer requirements.

Since 1991, the Norwegian government has implemented a CO2 tax on a number of sectors, including offshore petroleum production. In 1996, the CO2 tax on offshore petroleum production on the Norwegian continental shelf was around NOK 210 (33 USD) per tonne of CO2. Norway's Greenhouse Gas Emission Trading Act entered into force in 2005, and Norway joined the EU Emissions Trading System (ETS) in 2008. This combination of charges on offshore petroleum extraction operations means that operators on the Norwegian continental shelf can presently pay up to NOK 500 (60 USD) per tonne of CO2 (see Norske Petroleum here). The need to process Sleipner West gas to meet the European market specification cap of 2.5 per cent CO2 for natural gas, the introduction of CO2 taxation on the offshore petroleum sector, and a commitment to sustainable energy production, led Statoil to capture and store CO2 in a deep geological formation at Sleipner.

This development was the world’s first demonstration of CCS technology for a deep saline reservoir. The injection rate of almost one Mtpa also makes the project one of the largest demonstrations of CCS in the world to date.

Production from the Sleipner West field is tied back to the gas treatment and transportation infrastructure facilities located at Sleipner East 12.5 kilometres / 7.8 miles away. The unprocessed well-stream from the Sleipner B wellhead platform on Sleipner West is piped to the Sleipner T gas treatment platform at Sleipner East where the carbon dioxide is removed using a conventional amine based process. The processed natural gas is then routed to market via the Sleipner A drilling and production platform where, together with Troll field gas, it is transported to Europe through the Zeepipe and Statpipe system. Unstabilised condensate is piped to Karstø north of Stavanger for processing to stabilised condensate and natural gas liquids for on-shipping.

The captured CO2 is compressed and also routed to Sleipner A where it is injected via well 16/9-A-16 into the Utsira Formation, a sandstone reservoir 250 metres / 820 feet thick.  The reservoir unit is at a depth of 800-1,100 metres / 2,625-3,610 feet below the sea level. The seal to the reservoir is provided by a 700 metre / 2,430 feet thick gas-tight caprock above the Utsira Formation.

Approximately 0.8 million tonnes of CO2 has been injected per annum on average. The purity of the CO2 is at 98 per cent. The remaining 2 per cent is mostly methane.

Around 16.5 million tonnes of COhas been injected since inception to January 2017. Initial development plans for Sleipner West indicated the amount of CO2 to be injected over the field’s expected life (25 years) was around 25 million tonnes. A lower CO2 content and a decreasing production profile for Sleipner West has seen this figure revised to around 17.5 million tonnes by 2020. Since 2014, the CO2 capture facilities at Sleipner T process an additional 100,000 – 200,000 tonnes per annum of COassociated with gas production from the Gudrun field, which ties in to the facilities at Sleipner East.

Subsurface CO2 storage at the Sleipner field was originally approved as part of the hydrocarbon production activities according to the Norwegian Petroleum Law. In 2016, it received approval according to the Environmental Protection Law and its CCS-relevant regulations.

An extensive program to monitor and model the distribution of injected CO2 in the Utsira Formation has been undertaken by a number of organisations (and has been partly funded by the European Union). This program includes a baseline 3D seismic survey and eight time lapse (4D) seismic surveys, four seabed micro gravimetric surveys, one electromagnetics survey and two seabed imaging surveys.

Latitude: 57.7159 N

Longitude: 1.87866 E

Project data is current as at 20/06/2017