16/1-9
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General information
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Wellbore history
GeneralThe 16/1-9 Draupne prospect is located on the eastern margin of the South Viking Graben in the North Sea. The structure is situated in the eastern part of the Gudrun Terrace and the western flank of the Utsira High. The primary target was a faulted anticline trap within Hugin/Sleipner reservoir sandstones of Middle Jurassic Bajocian - Callovian age. A secondary target was mapped on a four way dip closure within the Paleocene top Heimdal level, the Gugne prospect. Well 16/1-9 was planned as a vertical well with TD ca 50 m into the Hugin/Sleipner Formation if water bearing, or ca 50 m into the Triassic Skagerrak Formation in case of a discovery.Operations and resultsWildcat well 16/1-9 was spudded with the semi-submersible installation Bredford Dolphin on 19 February 2008 and drilled to TD at 2544 m in the Late Triassic Skagerrak Formation. A pilot hole was drilled prior to the 36" section. No signs of shallow gas were observed or seen on MWD logs. Significant downtime resulted from a shallow water flow beside the well (5.2 days), wait on weather (4.3 days), BOP acoustic failure (3.5 days), poor hole conditions (2.9 days) and stuck wire line (2.2 days). The well was drilled with Seawater and sweeps down to 600 m, with KCl/GEM mud from 600 m to 1281 m, and with Performadril mud from 1281 m to TD.The secondary target Heimdal Formation was entered at 2126.0 m (2123.2 m TVD), approximately 100 meters deeper than the prognosed depth, and it was dry. The Sleipner Formation sandstone was encountered at 2399.0 m (2393.2 m TVD), 167 TVD meters deeper than prognosed. The Skagerrak Formation was encountered at 2411 m (2405 m TVD), 23 TVD meters shallower than prognosed. The wire line logs proved a thin gas cap from 2399 m (2368 m TVD MSL) to about 2407.5 m (2376.5 m TVD MSL), oil down to 2442.5 m (2411 m TVD MSL) and oil shows on cuttings down to 2448 m. There was no indication of an oil-water contact from the logs. The reservoir quality is variable with good reservoir sands disrupted by shale layers and cemented zones (carbonate nodules/clasts).Apart from shows in the Sleipner and Skagerrak formations reservoir zone oil shows were observed also in thin Hordaland Group sandstones from 1510 to 1540 meters.One core was cut at 2417.5 to 2426.9 m in the Skagerrak Formation with 100% recovery. The MDT tool was run on wire line. One gas and one oil sample were taken at 2405.0 and 2419.5 m respectively. During the MDT run the wire line cable got stuck and further wire line operations were terminated.The well was permanently abandoned on 22 April 2008 as an oil discoveryTestingNo drill stem test was performed. -
Cuttings at the Norwegian Offshore Directorate
Cuttings at the Norwegian Offshore Directorate Cuttings available for sampling?YESCuttings at the Norwegian Offshore Directorate Cutting sample, top depth [m]Cutting samples, bottom depth [m]610.002544.00 -
Cores at the Norwegian Offshore Directorate
Cores at the Norwegian Offshore Directorate Core sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom12417.52426.8[m ]Cores at the Norwegian Offshore Directorate Total core sample length [m]9.3Cores at the Norwegian Offshore Directorate Cores available for sampling?YES -
Palynological slides at the Norwegian Offshore Directorate
Palynological slides at the Norwegian Offshore Directorate Sample depthDepth unitSample typeLaboratory2409.0[m]DCAPT2412.0[m]DCAPT2415.0[m]DCAPT2418.0[m]DCAPT2421.0[m]DCAPT -
Lithostratigraphy
Lithostratigraphy Top depth [mMD RKB]Lithostrat. unit13675781893993911041123119012971331159816321693179319791979204120902126214321762179217922212221226722672399239924562456 -
Composite logs
Composite logs Document nameDocument formatDocument size [MB]pdf0.46 -
Geochemical information
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Logs
Logs Log typeLog top depth [m]Log bottom depth [m]MDT23992445MWD - GR EWR136600MWD - GR EWR6001281MWD - GR EWR PWD ALD CTN BAT12812544PEX HRLA MSIP3182532VSI4582530 -
Drilling mud
Drilling mud Depth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured2001.03Spudmud2351.04Spudmud4871.03Spudmud5671.03Spudmud6001.1210.0KCL/Glycol/Polymer6001.04Spudmud6241.1212.0KCl/GEM/Polymer8131.1418.0KCl/GEM/Polymer11301.3530.0PERFORMADRIL12231.1521.0KCl/GEM/Polymer12311.3634.0PERFORMADRIL12501.3534.0PERFORMADRIL12811.2022.0KCl/GEM/Polymer12811.2424.0KCl/GEM/Polymer12841.2124.0KCl/GEM/Polymer13391.2224.0PERFORMADRIL14761.2224.0PERFORMADRIL15971.2225.0PERFORMADRIL17131.2324.0PERFORMADRIL18351.2730.0PERFORMADRIL18971.3532.0PERFORMADRIL19711.3532.0PERFORMADRIL20391.3533.0PERFORMADRIL21301.3532.0PERFORMADRIL22061.3535.0PERFORMADRIL22341.3533.0PERFORMADRIL22491.3533.0PERFORMADRIL22751.3535.0PERFORMADRIL23001.3535.0PERFORMADRIL23411.3534.0PERFORMADRIL24021.3537.0PERFORMADRIL24171.3534.0PERFORMADRIL24181.3536.0PERFORMADRIL24851.3540.0PERFORMADRIL25441.3535.0PERFORMATROL -
Pressure plots
Pressure plots The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.Pressure plots Document nameDocument formatDocument size [MB]pdf0.23