10/7-1
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General information
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Wellbore history
GeneralWell 10/7-1 is located at the southeastern end of the Egersund Basin in the North Sea. The objective of the well was to test the Tott prospect, a faulted anticline over a salt wall. The Middle Jurassic Bryne formation was the primary objective. A thin Sandnes formation sandstone overlying the Bryne was interpreted to be possible at the drilled location.Operations and resultsWildcat well 10/7-1 was spudded with the semi-submersible installation Sonat Arcade Frontier on 28 June 1992 and drilled to TD at 1890 m in the Late Permian Zechstein Group. The well was drilled with seawater and gel down to 793 m and with KCl/polymer mud from 793 m to TD.Good reservoir quality sandstones were encountered in both the Sandnes and Bryne formations of the Vestland group. The top of the Sandnes formation was penetrated at 1539 m; top of the Bryne at 1632 m. Total thickness of the Vestland group is 297 m. From drill cuttings, fair to good visible porosity was observed in fine to coarse-grained sandstones throughout the Vestland group. Reservoir quality is good, with a net sand/gross thickness ratio of 54.5% using a 12% porosity cut-off. Using the same cut-off value the average porosity of the reservoir sandstones in the Vestland group is 23.3%. Bathonian age sediments (Bryne Formation) rested directly on Late Permian Zechstein salt at 1836 m. Occasional, spotty shows were observed in cuttings from the Sandnes and Bryne Formations. These marginal shows were interpreted to be sourced from in-situ carbonaceous material and not as migrated hydrocarbons. Analysis of the wire line logs and wire line pressure data clearly indicated that the sandstones of the Vestland group were water bearing. Organic geochemical analyses showed Total Organic Carbon (TOC) from 1.0 to 3.19 % and Hydrogen Index (HI) from 79 to 224 mg HC/g TOC in the Late Jurassic shales, which was classified as a poor oil and gas source. Associated with coals in the Vestland group were gas prone sediments with TOC values ranging from 1.64 - 6.14% and HI values of 118 to 223. The well was found immature for oil and gas generation; maximum vitrinite reflectance, recorded near TD, was 0.45 %Ro. Extractable organic matter contained low to modest amounts of immature hydrocarbons associated with local shales and coals, consistent with the trace shows recorded during drilling.One conventional core was cut in the Sandnes formation, from 1561 to 1566.5 m, where the core jammed. The recovered core (3.95 m) consisted of sandstone with a thin claystone/shale bed at the base. Shows were not observed in the core. Core analysis indicated generally fair to good porosity and permeability. FMT pressures also indicated fair to good permeability throughout the Vestland group. No fluid sample was taken.The well was permanently abandoned on 30 July 1992 as a dry hole.TestingNo 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]800.001890.00 -
Cores at the Norwegian Offshore Directorate
Cores at the Norwegian Offshore Directorate Core sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom11561.01565.2[m ]Cores at the Norwegian Offshore Directorate Total core sample length [m]4.2Cores 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 typeLaboratory800.0[m]DCRRI800.0[m]DC810.0[m]DCRRI820.0[m]DCRRI830.0[m]DCRRI830.0[m]DC860.0[m]DC875.0[m]DC890.0[m]DC920.0[m]DC950.0[m]DC975.0[m]DC1010.0[m]DC1029.0[m]DC1084.0[m]DC1130.0[m]DC1160.0[m]DC1186.5[m]SWC1220.0[m]DC1230.0[m]DC1250.0[m]DC1280.0[m]DC1290.0[m]DC1320.0[m]DC1333.0[m]SWC1350.0[m]DC1370.0[m]DC1378.0[m]SWC1400.0[m]DC1436.5[m]SWC1440.0[m]DCGEUS1460.0[m]DCGEUS1462.0[m]DC1480.0[m]DCGEUS1490.0[m]DC1500.0[m]DC1500.0[m]DCGEUS1510.0[m]DC1520.0[m]DCGEUS1535.0[m]SWC1540.0[m]DC1540.0[m]DCGEUS1545.0[m]SWC1550.0[m]DC1560.0[m]DCGEUS1561.0[m]DC1561.6[m]C1565.0[m]DC1565.2[m]C1581.0[m]DCGEUS1587.0[m]DC1600.0[m]DC1600.0[m]DCGEUS1618.0[m]DCGEUS1619.0[m]SWC1630.0[m]DC1640.0[m]DCGEUS1650.0[m]DC1660.0[m]DCGEUS1660.0[m]DCGEUS1670.0[m]DC1680.0[m]DCGEUS1690.0[m]DC1700.0[m]DCGEUS1710.0[m]DC1715.0[m]SWC1720.0[m]DCGEUS1730.0[m]DC1733.0[m]SWC1740.0[m]DCGEUS1750.0[m]DC1759.0[m]DC1760.0[m]DCGEUS1760.0[m]DCGEUS1765.0[m]DC1775.0[m]DC1780.0[m]DC1780.0[m]C1780.0[m]DC1800.0[m]DCGEUS1805.0[m]DC1805.0[m]DC1820.0[m]DCGEUS1820.0[m]DCGEUS1825.0[m]SWC1830.0[m]C1830.0[m]DCGEUS1840.0[m]C1850.0[m]SWC1850.0[m]DC1865.0[m]C1877.0[m]SWC1886.0[m]SWC1890.0[m]DC1890.0[m]C -
Lithostratigraphy
Lithostratigraphy Top depth [mMD RKB]Lithostrat. unit110451652652673720781102212981298138614861539153916321836 -
Composite logs
Composite logs Document nameDocument formatDocument size [MB]pdf0.26 -
Geochemical information
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Documents – reported by the production licence (period for duty of secrecy expired)
Documents – reported by the production licence (period for duty of secrecy expired) Document nameDocument formatDocument size [MB]pdf1.36pdf7.24pdf17.96 -
Logs
Logs Log typeLog top depth [m]Log bottom depth [m]CBL110656CNL ZDL GR SP CAL7771888DIPMETER7771888DLL MLL AC GR SP CAL7771888FMT GR15421823MWD EQW150786SONAN120656SWC8751886TEMPERATURE110665VSP ZO4001845 -
Casing and leak–off tests
Casing and leak–off tests Casing typeCasing diam.
[inch]Casing depth
[m]Hole diam.
[inch]Hole depth
[m]LOT/FIT mud eqv.
[g/cm3]Formation test typeCONDUCTOR30145.036147.00.00LOTINTERM.13 3/8779.017 1/2793.00.00LOTOPEN HOLE1890.012 1/41890.00.00LOT -
Drilling mud
Drilling mud Depth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured1151.04WATER BASED1321.04WATER BASED1471.04WATER BASED1471.04WATER BASED5051.04WATER BASED6661.2038.0WATER BASED7931.11WATER BASED7931.04WATER BASED8041.1110.0WATER BASED8891.1410.0WATER BASED9871.1410.0WATER BASED10701.1410.0WATER BASED12301.1611.0WATER BASED12301.168.0WATER BASED12881.2636.0WATER BASED13791.2942.0WATER BASED15411.3341.0WATER BASED15651.3744.0WATER BASED16811.3745.0WATER BASED18421.3743.0WATER BASED18901.3743.0WATER BASED -
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]pdf0.17