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Snøhvit Oil and Gas Field is a shut in oil and gas field in Norway.
Project Details
Main Data
Table 1: Field-level project details for Snøhvit Oil and Gas Field
| Unit name | Status | Operator | Owner | Discovery year | FID* year | Production start year |
|---|---|---|---|---|---|---|
| Snøhvit | Shut in[1] | Equinor Energy AS[2] | Equinor Energy AS (36.79%); Petoro AS (30.0%); TotalEnergies E&P Norge AS (18.4%); Neptune Energy Norge AS (12.0%); Wintershall DEA Norge AS (2.81%)[3] | 1984[4] | – | 2007[4] |
Production and Reserves
Table 2: Reserves of Snøhvit Oil and Gas Field
| Fuel Description | Reserve Classification | Quantity | Units | Data Year | Source |
|---|---|---|---|---|---|
| Condensate | original recoverable reserves | 3.82 | million bbl | 2022 | [5] |
| Condensate | remaining reserves | 2.19 | million bbl | 2022 | [5] |
| Gas | original recoverable reserves | 209720 | million m³ | 2022 | [5] |
| Gas | remaining reserves | 142380 | million m³ | 2022 | [5] |
| NGL | original recoverable reserves | 95.47 | million bbl | 2020 | [5] |
| NGL | remaining reserves | 59.28 | million bbl | 2020 | [5] |
| NGL | original recoverable reserves | 50.88 | million bbl | 2022 | [5] |
| NGL | remaining reserves | 30.44 | million bbl | 2022 | [5] |
| Oil | original recoverable reserves | 0 | million bbl | 2022 | [5] |
| Oil | remaining reserves | 0 | million bbl | 2022 | [5] |
| condensate | original recoverable reserves | 3.74 | million bbl | 2020 | [5] |
| condensate | remaining reserves | 2.32 | million bbl | 2020 | [5] |
| gas | original recoverable reserves | 209470 | million m³ | 2020 | [5] |
| gas | remaining reserves | 145690 | million m³ | 2020 | [5] |
| oil | original recoverable reserves | 0 | million bbl | 2020 | [5] |
| oil | remaining reserves | 0 | million bbl | 2020 | [5] |
Table 3: Production from Snøhvit Oil and Gas Field
| Category | Fuel Description | Quantity | Units | Data Year | Source |
|---|---|---|---|---|---|
| cumulative production | condensate | 1.56 | million bbl | 2020 | [6] |
| cumulative production | gas | 63348.42 | million m³ | 2020 | [6] |
| cumulative production | NGL | 36.39 | million bbl | 2020 | [6] |
| cumulative production | oil | 0 | million bbl | 2020 | [6] |
| cumulative production | gas | 63312.08 | million m³ | 2021 | [6] |
| cumulative production | gas | 67001.81 | million m³ | 2022 | [6] |
| cumulative production | oil | 0 | million bbl | 2021 | [6] |
| cumulative production | oil | 0 | million bbl | 2022 | [6] |
| cumulative production | NGL | 36.37 | million bbl | 2021 | [6] |
| cumulative production | NGL | 37.97 | million bbl | 2022 | [6] |
| cumulative production | Condensate | 1.56 | million bbl | 2021 | [6] |
| cumulative production | Condensate | 1.63 | million bbl | 2022 | [6] |
| production | condensate | 0.08 | million bbl/y | 2020 | [6] |
| production | gas | 3776.05 | million m³/y | 2020 | [6] |
| production | NGL | 1.88 | million bbl/y | 2020 | [6] |
| production | oil | 0 | million bbl/y | 2020 | [6] |
| production | gas | 0 | million m³/y | 2021 | [6] |
| production | gas | 3689.73 | million m³/y | 2022 | [6] |
| production | oil | 0 | million bbl/y | 2021 | [6] |
| production | oil | 0 | million bbl/y | 2022 | [6] |
| production | NGL | 0 | million bbl/y | 2021 | [6] |
| production | NGL | 1.6 | million bbl/y | 2022 | [6] |
| production | Condensate | 0 | million bbl/y | 2021 | [6] |
| production | Condensate | 0.07 | million bbl/y | 2022 | [6] |
Location
Table 4: field-level location details for Snøhvit Oil and Gas Field
| Location | Coordinates (WGS 84) |
|---|---|
| Offshore, Norway[2] | 71.4, 20.5 (exact)[2] |
The map below shows the exact location of the field:
Background
Snøhvit was discovered in 1984 and its and the plan for development and operation (PDO) was approved in 2002.[7] Three gas fields --the Snohvit, Askeladd and Albatross fields-- are included in the project. The Snøhvit and Albatross wells came on stream in 2007, with the Askeladd development expected to start production "after 2020" according to Equinor.[8]
Snøhvit LNG Project consists of nine wells, eight for production and one for injecting carbon dioxide.[8]
Gas from Snøhvit, Askeladd and Albatros is transported through a 160-kilometre pipeline to Hammerfest LNG Snohvit Terminal.[7] Carbon dioxide is returned to the field by pipeline for injection into the Stø reservoir in a process known as Carbon Capture and Storage (CCS).
Phase 2 (Askeladd)
In 2018, Equinor announced that it alongside partners in the project had "decided to invest just over NOK 5 billion in the further development of the Snøhvit field in the Barents Sea."[9] Askeladd, also known as Snøhvit Phase 2, was expected to supply 21 billion cubic metres of gas and two million cubic metres of condensate to Hammerfest LNG Snohvit Terminal. The Petroleum Safety Authority (PSA) gave Equinor its consent for Askeladd Phase 1 facilities in September 2020.[10] At that time, it was expected that production from Askeladd would begin before 2020 year end, however, a fire at the Hammerfest LNG Snohvit Terminal led the the Snøhvit, Albatross and Askeladd fields to be shut-in.[11]
Carbon Capture and Storage (CCS)
Statoil states that the gas which is piped from the Snøhvit field to Melkøya processing plant outside Hammerfest contains 5-8% carbon dioxide. The C02 is separated from the natural gas, piped back via a 153km pipeline to the "edge of the Snøhvit reservoir" and reinjected at a depth of 2600 metres beneath the seabed. Statoil states that "at full capacity on Snøhvit, 700,000 tonnes of CO2 will be stored per year". The company also states that "a shale cap which lies above the sandstone will seal the reservoir and ensure that the CO2 stays underground without leaking to the surface."[12]
Articles and Resources
Additional data
To access additional data, including an interactive map of oil and gas extraction sites, a downloadable dataset, and summary data, please visit the Global Oil and Gas Extraction Tracker on the Global Energy Monitor website.
References
- ↑ https://web.archive.org/web/20210626165341/https://www.investegate.co.uk/article.aspx?id=202011180800076469F. Archived from the original on 26 June 2021.
{{cite web}}: Missing or empty|title=(help) - ↑ 2.0 2.1 2.2 "Map Services - Field outlines". Norwegian Petroleum Directorate. Archived from the original on March 17, 2021. Retrieved March 8, 2021.
- ↑ "Factpages: Table – Licensees". Norwegian Petroleum Directorate. Archived from the original on March 17, 2021. Retrieved March 8, 2021.
- ↑ 4.0 4.1 https://web.archive.org/web/20230414155608/https://www.norskpetroleum.no/en/facts/field/snohvit/. Archived from the original on 14 April 2023.
{{cite web}}: Missing or empty|title=(help) - ↑ 5.00 5.01 5.02 5.03 5.04 5.05 5.06 5.07 5.08 5.09 5.10 5.11 5.12 5.13 5.14 5.15 Norwegian Petroleum Directorate (2023). "Table – Reserves". Norwegian Petroleum Directorate. Archived from the original on May 18th, 2023. Retrieved May 15, 2023.
{{cite web}}: Check date values in:|archive-date=(help) - ↑ 6.00 6.01 6.02 6.03 6.04 6.05 6.06 6.07 6.08 6.09 6.10 6.11 6.12 6.13 6.14 6.15 6.16 6.17 6.18 6.19 6.20 6.21 6.22 6.23 "Production - Saleable - Yearly - by field". Norwegian Petroleum Directorate. 2021. Archived from the original on March 7, 2021. Retrieved March 7, 2021.
- ↑ 7.0 7.1 Cite error: Invalid
<ref>tag; no text was provided for refs named:0 - ↑ 8.0 8.1 "Snøhvit - equinor.com". www.equinor.com. Retrieved 2021-02-05.
- ↑ "Investing in Askeladd - Investing in Askeladd - equinor.com". www.equinor.com. Retrieved 2021-02-05.
- ↑ "Equinor cleared to use Askeladd Phase 1 facilities". Offshore Energy. 2020-09-16. Retrieved 2021-02-05.
- ↑ "Investegate |Neptune Energy Group Announcements | Neptune Energy Group: 3rd Quarter Results". www.investegate.co.uk. Retrieved 2021-02-05.
- ↑ Statoil, "Carbon storage started on Snøhvit", Media Release, April 2008.
