The discovery well, drilled in 2010, proved up 60-120mmbbl and 1-3bcm in Maria South. Now the company is drilling Maria North (6407/1-5S), which is classified as an appraiser, although this is a separate structure. The dry-hole prognosis was 60 days, plus 20 days for possible testing. The well was spudded by the semi Borgland Dolphin on 1 February, so testing could now be under way.

The result of this well will obviously contribute to the concept decision, although according to Wintershall’s draft environmental impact assessment programme, this will not be taken until the end of the year. While the programme does not explicitly say so, it looks as if the fpso solution will come into play if further volumes are proven up in Maria North, while the subsea tieback will be the choice if development is restricted to Maria South.

One or both

If both structures are developed, there will be four subsea production wells and two water injectors – two plus one on each structure. Each set of wells is expected to take 250 days to drill with drilling due to start in 2015. So if only Maria South is developed, start-up will take place in 2016, and if both structures, the year after. Capex is put at NOK21bn for the fpso option and NOK12bn for the subsea solution.

Åsgard, Kristin and Heidrun are being evaluated as possible tieback hosts. Why Heidrun is interesting is not explained in the draft EIA programme. It lies 39km to the north, while Åsgard is only 15km to the northwest and Kristin about 25km to the west.

A third possibility, Wintershall says, is a joint development with Statoil’s Trestakk, which lies about 12km to the southwest. Trestakk was once on Statoil’s development agenda, but seems to have run into some sort of problem. Reserves are estimated by the NPD at 48mmbbl and 1.9bcm.

Meanwhile, Wintershall has made a promising light oil discovery at Skarfjell with reserves provisionally estimated at 60-160mmbbl and may be thinking floater here as well.

The wildcat (35/9-7) was drilled by the semi Songa Delta in 368m. Due to the limited duration of the rig slot, it could not be tested, and appraisal drilling will be required to confirm its commerciality. However reservoir qualities are good and despite identifying a 168m gross oil column, the oil/water contact was not found.

According to partner Agora, 3-D seismic data is now being collected over the area. It’s good news also for Cairn Energy, which has just agreed to take over Agora.

Skarfjell is in an interesting location, lying about 8km north of Wintershall’s Grosbeak find (35/12-2) and 12km south of RWE Dea’s Titan discovery (35/9-6S). RWE is a partner in Skarfjell.

According to the Norwegian Petroleum Directorate, Titan contains 26mmbbl of oil plus 3.3bcm while Grosbeak, following last year’s disappointing appraisal, is estimated to hold 54mmbbl of oil. Skarfjell could become a hub for developing all three fields, hosting a floater with subsea tiebacks.