The Dvalin gas field, previously known as Zidane, discovered in 2010, is DEA’s first own operated field development project in Norway. The redesigned development concept aims for sustainable profitability, while applying the highest safety and environmental protection measures.
The field is located in Production Licence (PL) 435, approximately 15 kilometres northwest of the Heidrun field and 35 kilometres south of the Skarv field in the Norwegian Sea. The licence was awarded in the Awards in Predefined Areas (APA) 2006.
The Norwegian authorities have approved the Plan for Development and Operation (PDO). First gas is expected in 2020.
In the 1980s, the Dvalin field was initially deemed to not hold much in the way of promise for the oil industry, due to a lack of success in exploration by other companies. As time passed, however, innovative ideas and approaches revealed new findings, and in 2007 a consortium, with DEA as the operator company, was granted the PL 435 licence.
The first major gas discovery was reported in September 2010, when the first exploration well was drilled on the Dvalin field. A gas-bearing reservoir with a thickness of 150 metres was encountered in the Fangst formation (Dvalin East). A second gas-bearing reservoir with a thickness of 140 metres was discovered in 2012 with a second exploration well (Dvalin West).
Field Development – Efficiency increased
The Dvalin field development programme includes a tie-in agreement between the Dvalin licence and the Heidrun Unit. The field development is based on a proven technical concept with four subsea wells tied back to the existing Heidrun host platform. A four-slot template will be installed on the seabed with flow-lines and umbilical connected to Heidrun. On the Heidrun platform, a new 4500-tonne module for processing and compression of gas will be installed. Statoil will perform all work at Heidrun and DEA will perform all subsea and subsurface work as Dvalin operator.
The gas from Dvalin will be transported to Heidrun via a 14.9-kilometre pipeline. From there, it will be sent to the Polarled trunk line via a 7.5-kilometre pipeline before it will be further processed to dry gas spec at the Nyhamna onshore gas terminal. Finally, the gas will be transported via Gassled to the market.
The licensees managed to reduce project costs by more than twenty per cent compared to the initial planning. This is the result of a more efficient project execution and the simplification of some of the solutions. Also, increased competition in the market has helped to cut costs.
|Operator||DEA Norge AS (55%)|
|Geography||Approximately 259 kilometres north of Kristiansund in the mid of Norway and 15 kilometres northwest of the Heidrun field and 35 kilometres south of the Skarv field in the Norwegian Sea|
Reservoir depth is 4,200 m
|Water depth||399 m|
|Estimated reserves||18.2 billion standard cubic metres of gas|
|Planned production start||2020|