Valhall
North Sea · Oil · Producing · Operator Aker BP ASA
Valhall is an oil field in the North Sea operated by Aker BP ASA, discovered in 1975 by wellbore 2/8-6. The Norwegian Offshore Directorate lists it as producing.
In the 12 months reported through August 2026 it sold 2.08 million Sm³ of oil equivalents (1.65 million Sm³ of oil, 0.32 billion Sm³ of gas), down 11% on the 12 months before.
Since October 1982 it has reported 167.3 million Sm³ of oil equivalents: 133.9 million Sm³ of oil and 25.3 billion Sm³ of gas.
2 companies hold it; the largest share is Aker BP ASA with 90%.
232 wellbores are on file for the field.
- 2.08
- mill Sm³ o.e., last 12 reported -11%
- 1.65
- mill Sm³ oil, last 12
- 0.32
- bill Sm³ gas, last 12
- 167.3
- mill Sm³ o.e. since Oct 1982
- 232
- wellbores on file
- 2
- licensees today
SODIR PRODUCTION PROFILES · SALEABLE VOLUMES · REPORTED THROUGH AUG 2026
Oil by month
TEN YEARS · SM³ SOLD
Last 12 months 1,650,763 · prior 12 1,866,064(-12%)
Gas by month
TEN YEARS · SM³ SOLD
Last 12 months 323,646,000 · prior 12 350,582,000(-8%)
Produced water by month
TEN YEARS · SM³ IN THE FIELD
Last 12 months 1,082,857 · prior 12 990,707(+9%)
Licensees
SHARES TODAY · UNIT VALHALL UNIT
| Company | Share | Since |
|---|---|---|
| Aker BP ASAOPERATOR | 90% | Jan 1, 2025 |
| INPEX Idemitsu Norge AS | 10% | Jan 1, 2025 |
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 | 156.4 | 30.1 | 6.3 | 0 | 198.5 |
| Remaining | 25.9 | 4.98 | 1.01 | 0 | 32.8 |
About the field
WRITTEN BY THE NORWEGIAN OFFSHORE DIRECTORATE
- Development
- Valhall is a field in the southern part of the Norwegian sector in the North Sea. The water depth is 70 metres. Valhall was discovered in 1975, and the initial plan for development and operation (PDO) was approved in 1977. The field was originally developed with three facilities for accommodation (QP), drilling (DP), and processing and compression (PCP). The production started in 1982. A PDO for a wellhead facility (WP) was approved in 1995 and for a water injection platform (IP) in 2000. Bridges connect the platforms. A PDO for two wellhead platforms on the northern and southern flanks was approved in 2001. A PDO for Valhall Redevelopment was approved in 2007. The plan included an accommodation and processing platform (PH) to replace aging facilities on the field. The PH-platform is supplied with power from shore. A PDO for Valhall Flank West which included a normally unmanned wellhead platform was approved in 2018, and the production started in 2019. An amended PDO for a new production and wellhead platform (PWP) was approved in June 2023.
- Reservoir
- Valhall produces oil from chalk in the Upper Cretaceous Hod and Tor Formations. The reservoir depth is 2400 metres. The Tor Formation chalk is fine-grained and has good reservoir quality. Considerable fracturing allows oil and water to flow more easily than in the underlying Hod Formation.
- Recovery strategy
- The field was initially produced with pressure depletion and compaction drive. Water injection in the centre of the field started in 2004. Chalk compaction as a result of pressure depletion and water weakening has led to seabed subsidence. Gas lift is used to optimise production in most of the production wells.
- Transport
- Oil and NGL (Natural Gas Liquids) are routed via pipeline to the Ekofisk field and further to Teesside in the UK. Gas is sent via Norpipe to Emden in Germany.
- Status
- The Valhall field has produced more than one billion barrels of oil equivalents, which is three times more than the original PDO estimate. New completion technology to increase recovery from the tight chalk reservoir is implemented in a new producer drilled on the northern flank of Valhall. Drilling of new wells will continue in the foreseeable future. Decommissioning of the QP, PCP and DP facilities must be completed by the end of 2026. Start-up of production from the new platform (PWP) is planned for 2027.
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 | 1.02 | 0.2 | 0.06 | 0 | 1.28 | 0.69 |
| 2025 | 1.78 | 0.35 | 0.11 | 0 | 2.24 | 1.02 |
| 2024 | 2.03 | 0.35 | 0.13 | 0 | 2.51 | 1 |
| 2023 | 2 | 0.34 | 0.12 | 0 | 2.47 | 0.91 |
| 2022 | 2.04 | 0.35 | 0.13 | 0 | 2.52 | 0.86 |
| 2021 | 2.4 | 0.4 | 0.15 | 0 | 2.95 | 0.93 |
| 2020 | 2.64 | 0.41 | 0.17 | 0 | 3.23 | 0.94 |
| 2019 | 2.05 | 0.32 | 0.11 | 0 | 2.47 | 0.84 |
| 2018 | 1.86 | 0.31 | 0.09 | 0 | 2.26 | 0.85 |
| 2017 | 1.77 | 0.31 | 0.08 | 0 | 2.16 | 0.79 |
| 2016 | 2 | 0.37 | 0.1 | 0 | 2.47 | 0.68 |
| 2015 | 2.4 | 0.44 | 0.12 | 0 | 2.96 | 0.6 |
| 2014 | 2.23 | 0.38 | 0.11 | 0 | 2.72 | 0.49 |
| 2013 | 1.77 | 0.24 | 0.08 | 0 | 2.08 | 0.34 |
| 2012 | 0.96 | 0.13 | 0.04 | 0 | 1.14 | 0.3 |
| 2011 | 1.64 | 0.25 | 0.07 | 0 | 1.97 | 0.35 |
| 2010 | 2.09 | 0.34 | 0.1 | 0 | 2.53 | 0.4 |
| 2009 | 2.27 | 0.35 | 0.11 | 0 | 2.73 | 0.41 |
| 2008 | 2.81 | 0.49 | 0.14 | 0 | 3.44 | 0.71 |
| 2007 | 3.41 | 0.61 | 0.17 | 0 | 4.19 | 0.69 |
| 2006 | 4.04 | 0.77 | 0.21 | 0 | 5.02 | 0.84 |
| 2005 | 4.83 | 0.96 | 0.23 | 0 | 6.02 | 0.58 |
| 2004 | 4.77 | 0.97 | 0.23 | 0 | 5.97 | 0.52 |
| 2003 | 4.16 | 0.63 | 0.2 | 0 | 4.98 | 0.34 |
| 2002 | 4.18 | 0.88 | 0.2 | 0 | 5.26 | 0.33 |
| 2001 | 4.36 | 0.88 | 0.21 | 0 | 5.46 | 0.27 |
| 2000 | 4.58 | 0.89 | 0.22 | 0 | 5.69 | 0.2 |
| 1999 | 5.31 | 1.04 | 0.26 | 0 | 6.6 | 0 |
| 1998 | 5.17 | 0.96 | 0.24 | 0 | 6.37 | 0 |
| 1997 | 4.53 | 0.94 | 0.25 | 0 | 5.72 | 0 |
| 1996 | 4.03 | 0.88 | 0.23 | 0 | 5.14 | 0 |
| 1995 | 3.49 | 0.79 | 0.19 | 0 | 4.47 | 0 |
| 1994 | 3.15 | 0.67 | 0.17 | 0 | 3.99 | 0 |
| 1993 | 3.54 | 0.8 | 0.19 | 0 | 4.53 | 0 |
| 1992 | 4.05 | 0.93 | 0.23 | 0 | 5.2 | 0 |
| 1991 | 3.74 | 0.82 | 0.25 | 0 | 4.81 | 0 |
| 1990 | 4.16 | 0.92 | 0.38 | 0 | 5.45 | 0 |
| 1989 | 4.24 | 0.84 | 0.38 | 0 | 5.46 | 0 |
| 1988 | 3.7 | 0.71 | 0.33 | 0 | 4.74 | 0 |
| 1987 | 3.48 | 0.62 | 0.34 | 0 | 4.44 | 0 |
| 1986 | 2.54 | 0.43 | 0.28 | 0 | 3.25 | 0 |
| 1985 | 2.78 | 0.47 | 0.31 | 0 | 3.56 | 0 |
| 1984 | 2.84 | 0.51 | 0.24 | 0 | 3.6 | 0 |
| 1983 | 0.97 | 0.1 | 0.07 | 0 | 1.13 | 0 |
| 19823 MONTHS | 0.09 | 0 | 0 | 0 | 0.09 | 0 |
Wellbores
Production 181 · Observation 20 · Injection 20 · Appraisal 7 · Shallow gas 3 · Wildcat 1
All 232 wellbores in Valhall, searchable → · Discovery wellbore 2/8-6 →
Operator history
- Aker BP ASANov 30, 2016 to today
- BP Norge ASMar 12, 2002 to Nov 29, 2016
- BP Amoco Norge ASDec 23, 1999 to Mar 11, 2002
- Amoco Norway Oil CompanyJun 2, 1977 to Dec 22, 1999
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/43548, documented in the API reference.