7225/3-2
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General information
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Wellbore history
GeneralWell 7225/3-2 was drilled on the Norvarg Dome on the Bjarmeland Platform in the Barents Sea. The objective of the well was to appraise the 7225/3-1 Norvarg gas discovery. Primary target was channel sandstones in the Kobbe Formation. Triassic sandstones within the Carnian section and the Upper Snadd Formation as well as Jurassic sandstones in the Stø Formation were secondary targets.Operations and resultsAppraisal well 7225/3-2 was spudded with the semi-submersible installation Leiv Eiriksson on 29 April 2013 and drilled to TD at 2210 m in the Early Triassic Klappmyss Formation. During drilling operations of the 26” hole section at 500 m the drill string parted. The fish was successfully retrieved. After this, the hole packed off at 525 m and 535 m in the 26” section. Most of the NPT in the well were related to these events. Further operation proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 554 m, with Glydril water based mud from 554 m to 1073 m, and with a water based mud from 1073 m to TD.Three main gas-filled reservoir layers were encountered in the Kobbe Formation. Channel A with top at 1590 m had a thickness of 18.7 m, a NTG of 76% and an average porosity and water saturation of 17% and 40% respectively. Channel D with top at 1775 m had a thickness of 33.1 m, a NTG of 51% and an average porosity and water saturation of 13% and 44% respectively. A third sandstone, “Anomaly 2”, with top at 1909.6 m had a thickness of 18.3 m, a NTG of 89% and an average porosity and water saturation of 13% and 48% respectively. All three had gas-down-to contacts. The secondary targets were water-wet. Shows (fluorescence and cut) were described on sandstones in the Kobbe Formation between 1550 m and 1950 m.Four 54 m core barrels were cut in the Kobbe Formation, with very low ROP, from 1553 to 1610 m (two cores) and from 1727 to 1757 m (two cores). While the recovery of last two cores was 100%, the first two gave respectively 86.1 and 76.4% recovery. MDT fluid samples were taken at 1600.7 m (dry gas), 1778. 31 m (filtrate + gas), 1788.59 m (filtrate), 1913.01 m (filtrate + gas + oil?), and 1923.64 m (filtrate + gas + oil?).The well was permanently abandoned on 7 August 2013 as a gas appraisal.TestingTwo Drill Stem Tests were performed in two channel sandstones in the Kobbe FormationDST 1 tested 207.33 m of perforations from 1725.05 to 1932.38 m. It produced 28500 Sm3 gas/day through a 40/64” choke. The maximum temperature in the test, measured during the clean-up flow was 54.9 °C.DST 2 tested 23 m of perforation from 1587.5 to 1610.5 m. It produced 167400 Sm3 gas/day through a 36/64” choke. The maximum temperature in the test, measured at end of build-up after the clean-up flow was 48.6 °C. -
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]554.002205.00 -
Cores at the Norwegian Offshore Directorate
Cores at the Norwegian Offshore Directorate Core sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom11553.01561.6[m ]21563.01598.2[m ]31727.01734.5[m ]41734.51757.0[m ]Cores at the Norwegian Offshore Directorate Total core sample length [m]73.8Cores at the Norwegian Offshore Directorate Cores available for sampling?YES -
Lithostratigraphy
Lithostratigraphy Top depth [mMD RKB]Lithostrat. unit4064064784786396747027297297908071168151715172141 -
Drill stem tests (DST)
Drill stem tests (DST) Test numberFrom depth MD
[m]To depth MD
[m]Choke size
[mm]1.01725193212.52.01587161020.6Drill stem tests (DST) Test numberFinal shut-in pressure
[MPa]Final flow pressure
[MPa]Bottom hole pressure
[MPa]Downhole temperature
[°C]1.02.0Drill stem tests (DST) Test numberOil
[Sm3/day]Gas
[Sm3/day]Oil density
[g/cm3]Gas grav. rel.airGOR
[m3/m3]1.0234002.0176200 -
Logs
Logs Log typeLog top depth [m]Log bottom depth [m]DP GR19131923GR MDT7321020GR PPC554687GR PPC MSIP CBL FMI ECS CAL6272200HNGR APS TLD HRLA MCFL SP CMR CA10722211HNGS GR CAL HRLA MCFL SP MSIP AP6811073LWD - RAB RES ECD GR DI FPWD10732210LWD - RAB RES GR PWD DI6871073LWD - RES GR PWD DI SEIS474687MDT 3D GR10961290MDT 3D GR15541781MSCT GR 40XL SWC15521974VSP GR3862140 -
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 typeCONDUCTOR30474.036474.00.00SURF.COND.20547.026554.00.00INTERM.13 3/8681.017 1/2687.01.18INTERM.9 5/81072.012 1/41073.01.75LINER72208.08 1/22210.02.30 -
Drilling mud
Drilling mud Depth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured4701.379.0KCl/Polymer-Glycol4751.35Spud mud5541.35Spud mud6401.378.0KCl/Polymer-Glycol6871.127.0KCl/Polymer-Glycol10731.3612.0KCl/Polymer-Glycol12231.3710.0KCl/Polymer-Glycol15541.3612.0KCl/Polymer-Glycol17571.3612.0KCl/Polymer-Glycol22101.35Calcium Chloride -
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]PDF0.26