Carbon capture and storage project
The Sleipner Vest (West) field is used as a facility for carbon capture and storage (CCS).[1][7][8] It is the world's first offshore CCS plant, operative since September 15, 1996.[9][10] The project, in the initial year, proved insecure due to sinking top sand.[9] However, after a re-perforation and an installation of a gravel layer in August 1997, CCS operations were secure.[9]
Equinor reported that as of 2018, one million tonnes of have been transported and injected into the formation yearly since 1996.[11] Equinor later stated that due to a problem with monitoring equipment, it had over-reported the amount of sequestered from 2017 to 2019 and released new figures that were around 30% less.[12] The project summary reports a capacity of up to 600 billion tonnes (≈660 billion tons).
The Sleipner West field has up to 9% concentration; Norway only allows 2.5% before imposing production export quality penalties, which may have been NOK 1 million/day ( ~$120,000US/ day).[1][13] Operating costs are US$17 / ton of injected, however, the company does not pay Norway's carbon tax of 1991[13] and receives carbon credit in the EU's emissions trading system.[14] Before the carbon tax, industries released poor quality into the atmosphere.[1] In a business-as-usual scenario, Norway's emissions would have had a total increase of 3% over 20 years if not for the CCS experiment.[5]
Carbon dioxide is treated on the Sleipner T treatment platform. Following treatment, carbon dioxide is transported to the Sleipner A platform where it is injected into the Utsira formation through a dedicated well c. 1000 meters under the seabed.[15] Using time-lapse gravity and seismic methods, the pioneering Sleipner carbon capture project confirmed the technological viability of injecting and measuring in an offshore reservoir, as well as the effectiveness of mitigating emissions through stable storage.[16] To avoid possible leakages that can result in health hazards and environmental destruction,[16] above the Utsira Formation injection site lies 30 seafloor gravity stations for monitoring under the title,[17] Saline Aquifer Storage.[18] These sites monitor microseismic activity along with gravitational forces and depth metrics.[17] Seafloor height, natural gas production, and tidal shifts
Explicitly regulated under Norway's petroleum law in December 2014 and in line with the EU's 2009/31/EC directive, monitoring objectives focus on assessing gas movement, shell stability, and the effectiveness of remedy scenarios in case of leakage.[9] From 2002 to 2005, measurements identified vertical changes in established metric boundaries, most likely attributed to erosion and marine life.[17] Onsite geochemical and reservoir simulations reveal a main buildup of under the formation's cap seal.[16] However, when the injections are eventually decommissioned, simulations show accumulation proximate to the cap seal in clay layers saturated with sand, which will result in solubility trapping.[16] This solubility trapping, caused by the multiple layers of clay and sand, prevents from rising beyond and will ultimately turn to mineral trapping in the substrate.[16] Furthermore, groundwater flow facilitates better distribution of gases and depressurization, lowering the risk of leakage.[16]
Natural gas pipelines' operator Gassco had proposed to build a 240 km carbon dioxide pipeline from Kårstø to transport carbon dioxide from the now decommissioned Kårstø power station.[20] While injection pipelines do not succumb to rusting when transporting ,[15] transport pipelines experience low temperatures and high pressures, resulting in dew formation, and subsequently, rust.[11]
