7220/10-1 is a wildcat exploration wellbore in the Barents Sea, drilled by Eni Norge AS, entered Aug 13, 2012, to 2,405 m in the Snadd Fm.
Discovery 7220/10-1 (Salina) · On the map →
- 2,405
- m total depth · 2,405 m vertical
- 341
- m water depth
- Aug 13, 2012
- entered · completed Oct 16, 2012
- Snadd Fm
- at total depth · Late Triassic
- 111.3
- m of core in 4 cores
- 79
- °C bottom-hole temperature
SODIR FACTPAGES · RECORD UPDATED FEB 20, 2026 · RELEASED OCT 16, 2014
On file for this wellbore
What the Directorate holds from this wellbore. Each opens the section that lists it.
Drilling
- Drilling facility
- SCARABEO 8 · Semisub steel
- Drilling days
- 65
- Kelly bushing elevation
- 34 m
- Maximum inclination
- 0.89999998°
- Drilling permit
- 1413-L
- Licensing round
- 20
- Plugged and abandoned
- —
- Core samples available
- Yes
- Cuttings samples available
- Yes
- Position · ED50
- 72.01593° N, 20.05695° E
- Hydrocarbons in
- Kolmule Fm · Early Cretaceous
- Hydrocarbons in
- Stø Fm · Middle Jurassic
Well history
WRITTEN BY THE NORWEGIAN OFFSHORE DIRECTORATE
General
Well 7220/10-1 was drilled on the Salina Prospect in the south-west end of the Loppa High in the Barents Sea area. The primary exploration target for the well was to prove petroleum in Early Cretaceous to Late Jurassic reservoir rocks (Knurr and Hekkingen formations). The secondary target was to prove petroleum in Middle to Early Jurassic reservoir rocks (Stø, Nordmela, Tubåen and Fruholmen formations).
Operations and results
Wildcat well 7220/10-1 was spudded with the semi-submersible installation Scarabeo 8 on 13 August 2012 and drilled to TD at 2405 m in Late Triassic Snadd Formation. A 9 7/8" pilot hole was drilled from the seabed to 830 m to check for shallow gas. There was no indication of shallow gas. The well was drilled with seawater and hi-vis pills down to 688 m and with EMS-3100 water based mud (seawater) from 688 m to TD.
The well proved the presence of a 134 m reservoir consisting of sandstones and siltstones of Aptian age within the Kolmule Formation. Top of this sandstone was at 1291 m and the upper 36 m was gas bearing and had 20% average porosity and a net/gross of 96%. Extrapolation of MDT pressure gradients placed the gas-water contact at 1327 m. The reservoir quality decreases towards the base of the reservoir. Top Stø Formation was penetrated at 1513.5 m. It consisted of 132 m sandstone with very good reservoir quality. The upper 53 m was gas bearing and had average porosity of 20% and a net/gross of 90%. A clean gas-water contact was found at 1567 m. The gas in both reservoirs had isotopic profiles typical of thermogenic gases. The gas in the Stø Formation had more C2+ components than the gas in the Kolmule Formation.
Sandstone reservoirs were als
Around this wellbore
This wellbore on Sodir FactPages → · Press release →
About this data
Norwegian Offshore Directorate (Sodir) FactPages, mirrored nightly and used under the Norwegian Licence for Open Government Data (NLOD). Depths are metres along the wellbore from the kelly bushing unless a row gives its own unit; older cores are filed in feet. A zero the Directorate files for an unmeasured pressure, density, or temperature is shown as a dash.
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