NORWAY · FIELDS · NPDID 21675433
Edvard Grieg
North Sea · Oil · Producing · Operator Aker BP ASA
Edvard Grieg is an oil field in the North Sea operated by Aker BP ASA, discovered in 2007 by wellbore 16/1-8. The Norwegian Offshore Directorate lists it as producing.
In the 12 months reported through August 2026 it sold 1.55 million Sm³ of oil equivalents (1.34 million Sm³ of oil, 0.14 billion Sm³ of gas), down 13% on the 12 months before.
Since November 2015 it has reported 50.4 million Sm³ of oil equivalents: 44.1 million Sm³ of oil and 4.1 billion Sm³ of gas.
3 companies hold it; the largest share is Aker BP ASA with 65%.
39 wellbores are on file for the field.
- 1.55
- mill Sm³ o.e., last 12 reported -13%
- 1.34
- mill Sm³ oil, last 12
- 0.14
- bill Sm³ gas, last 12
- 50.4
- mill Sm³ o.e. since Nov 2015
- 39
- wellbores on file
- 3
- licensees today
SODIR PRODUCTION PROFILES · SALEABLE VOLUMES · REPORTED THROUGH AUG 2026
Oil by month
TEN YEARS · SM³ SOLD
Last 12 months 1,342,680 · prior 12 1,543,328(-13%)
Gas by month
TEN YEARS · SM³ SOLD
Last 12 months 139,852,000 · prior 12 150,202,000(-7%)
Produced water by month
TEN YEARS · SM³ IN THE FIELD
Last 12 months 3,025,834 · prior 12 3,026,746(0%)
Licensees
SHARES TODAY · LICENCE 338
| Company | Share | Since |
|---|---|---|
| Aker BP ASAOPERATOR | 65% | Sep 1, 2025 |
| OMV Norge AS | 20% | Sep 1, 2025 |
| Harbour Energy Norge AS | 15% | Sep 1, 2025 |
Production licence 338: ownership history and register messages →
Reserves
THE DIRECTORATE'S ESTIMATE · AS OF DEC 31, 2025
These are the Norwegian Offshore Directorate's own year-end estimates, shown as it publishes them. Petrora does not estimate reserves.
| Oil, mill Sm³ | Gas, bill Sm³ | NGL, mill tonnes | Condensate, mill Sm³ | O.e., mill Sm³ | |
|---|---|---|---|---|---|
| Originally recoverable | 54.4 | 5.1 | 1.51 | 0 | 62.3 |
| Remaining | 11.1 | 1.13 | 0.36 | 0 | 12.9 |
About the field
WRITTEN BY THE NORWEGIAN OFFSHORE DIRECTORATE
- Development
- Edvard Grieg is a field in the Utsira High area in the central North Sea, 35 kilometres south of the Grane and Balder fields. The water depth is 110 metres. Edvard Grieg was discovered in 2007, and the plan for development and operation (PDO) was approved in 2012. The field is developed with a fixed installation with a steel jacket and full process facility, and it utilises a jack-up rig for drilling and completion of wells. The production started in 2015. Since 2022, Edvard Grieg receives power from shore through the area solution for the Utsira High, and is therefore producing with very low CO2 emissions. The Solveig field is tied-back to Edvard Grieg. The Troldhaugen discovery is temporarily tied-back to Edvard Grieg for test production.
- Reservoir
- Edvard Grieg produces undersaturated oil from alluvial, aeolian and shallow marine sandstone and conglomerate of Late Triassic to Early Cretaceous age. The reservoir is at a depth of 1900 metres. The eservoir quality varies from moderate to very good in marine and aeolian sandstone, while the quality is poorer in alluvial sandstone and conglomerate. Oil is also proven in the underlying basement.
- Recovery strategy
- The field is produced by pressure support from water injection.
- Transport
- The oil is exported by pipeline to the Grane Oil Pipeline, which is connected to the Sture terminal. The gas is exported in a separate pipeline to the Scottish Area Gas Evacuation (SAGE) system in the UK.
- Status
- Edvard Grieg production has come off plateau. The field has been producing better than expected and the recoverable volumes have increased significantly since the PDO due to excellent reservoir performance. Several additional wells have been drilled and are planned going forward. Test production from the Troldhaugen discovery started in 2021 and continues.
Production by year
MONTHLY ROWS ADDED UP · NEWEST FIRST
| Year | Oil, mill Sm³ | Gas, bill Sm³ | NGL, mill Sm³ | Condensate, mill Sm³ | O.e., mill Sm³ | Water, mill Sm³ |
|---|---|---|---|---|---|---|
| 20268 MONTHS | 0.88 | 0.08 | 0.03 | 0 | 0.99 | 2.13 |
| 2025 | 1.46 | 0.17 | 0.09 | 0 | 1.72 | 2.97 |
| 2024 | 2.14 | 0.2 | 0.11 | 0 | 2.45 | 3.41 |
| 2023 | 4.14 | 0.43 | 0.25 | 0 | 4.82 | 3.04 |
| 2022 | 5.14 | 0.47 | 0.28 | 0 | 5.89 | 1.8 |
| 2021 | 5.69 | 0.49 | 0.28 | 0 | 6.46 | 0.91 |
| 2020 | 5.06 | 0.45 | 0.25 | 0 | 5.76 | 0.3 |
| 2019 | 5 | 0.5 | 0.25 | 0 | 5.75 | 0.15 |
| 2018 | 5.1 | 0.46 | 0.28 | 0 | 5.84 | 0.1 |
| 2017 | 5.41 | 0.5 | 0.28 | 0 | 6.18 | 0.07 |
| 2016 | 3.9 | 0.32 | 0.13 | 0 | 4.36 | 0.02 |
| 20152 MONTHS | 0.15 | 0.01 | 0 | 0 | 0.16 | 0 |
Wellbores
Production 20 · Appraisal 10 · Injection 4 · Observation 3 · Wildcat 2
All 39 wellbores in Edvard Grieg, searchable → · Discovery wellbore 16/1-8 →
Operator history
- Aker BP ASAJan 1, 2023 to today
- ABP Norway ASJun 30, 2022 to Dec 31, 2022
- Lundin Energy Norway ASApr 1, 2020 to Jun 29, 2022
- Lundin Norway ASJun 11, 2012 to Mar 31, 2020
This field on Sodir FactPages →
About this data
Norwegian Offshore Directorate (Sodir) FactPages, mirrored nightly and used under the Norwegian Licence for Open Government Data (NLOD). Production is saleable volume by month from the Directorate's profiles, cut at the latest month any field has reported; yearly and cumulative figures are those months added up. Shares are the current rows of the field's licensee history. Reserves are the Directorate's estimate.
Developers: this page as JSON is GET /v1/data/norway/fields/21675433, documented in the API reference.