16/7-2
Exploration · Wildcat · P&A · Gas · Esso Exploration and Production Norway A/S · PL 072
16/7-2 is a wildcat exploration wellbore in the North Sea, drilled by Esso Exploration and Production Norway A/S, entered Jan 11, 1982, to 3,146 m in the Rotliegend Gp.
Discovery 16/7-2 · On the map →
- 3,146
- m total depth · 3,146 m vertical
- 83
- m water depth
- Jan 11, 1982
- entered · completed Mar 30, 1982
- Rotliegend Gp
- at total depth · Early Permian
- 45.3
- m of core in 4 cores
- 97
- °C bottom-hole temperature
SODIR FACTPAGES · RECORD UPDATED MAR 1, 2026 · RELEASED MAR 30, 1984
On file for this wellbore
What the Directorate holds from this wellbore. Each opens the section that lists it.
Drilling
- Drilling facility
- GLOMAR BISCAY II · Semisub steel
- Drilling days
- 79
- Kelly bushing elevation
- 25 m
- Maximum inclination
- 2.75°
- Drilling permit
- 314-L
- Licensing round
- 6
- Plugged and abandoned
- —
- Core samples available
- Yes
- Cuttings samples available
- No
- Position · ED50
- 58.47403° N, 2.03420° E
- Hydrocarbons in
- Heimdal Fm · Paleocene
Well history
WRITTEN BY THE NORWEGIAN OFFSHORE DIRECTORATE
General
The 16/7-2 well was drilled on the western flank of the Utsira High in the North Sea. The primary objective was to test the presence of a stratigraphic trap in Paleocene sandstones. Secondary objectives were to test the Mesozoic structure for possible Triassic sands, and also to test the Zechstein carbonate and Rotliegendes sandstone plays. The well was the first to be drilled in connection with the 6th. License Round awards.
Operations and results
Well 16/7-2 was spudded with the semi-submersible installation Glomar Biscay II on 11 January 1982 and drilled to TD at 3146 m in Early Permian, Rotliegendes Group sediments. Drilling of the 36" and 26" holes went forth without any specific problems. While cementing the 20" casing, the cement slurry was overdisplaced. A remedial squeeze job was necessary. Problems also occurred when logging the 12 1/4" section due to tight hole. In the 8 1/2" inch section problems with the BOP choke valve/controls led to close to 9 days lost time, a major reason for the 38% non-productive time in this well. The well was drilled with seawater gel down to 171 m, and with lignite/lignosulphonate mud from 171 m to TD.
Top Lista Formation was encountered at 2268 m and contained 9.5 m net of gas from 2292 m in thin sandstone intervals, interbedded with shales. The average porosity is 22% and average water saturation is 47% in the net sand. The Heimdal Formation sandstones were massive, of very good reservoir quality, and contained 13.5 m of net gas sand in a gross gas sand interval of 13.5 m down to the gas/water contact at 2352 m. The average porosity is 26% and average water saturation is 34%. The well was drilled on the crest of a structurally limited trap and the gas accumulation is not connected to the 15/9 Paleocene Gamma discovery. In the Jurassic, 19 m of water wet Hugin Formation sand was encountered. The Zechstein dolomites and Rotliegendes sandstones were also wat
Around this wellbore
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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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