25/8-7
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Generell informasjon
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Brønnhistorie
GeneralExploration Well 25/8-7 is located East North-East of the Jotun Field. The two main objectives for drilling well 25/8-7 were to test the hydrocarbon potentials of the sandstones in the Lower Palaeocene Heimdal Formation (Krap prospect) and in the Middle Jurassic Hugin Formation.Operations and resultsWell 25/8-7 was spudded with the semi-submersible installation "Dyvi Stena" on 21 July 1995 and drilled to a total depth of 2380 m, 40 metres into the Early Jurassic Amundsen Formation. The well was drilled with seawater and high viscous pills through the 36" and 17 1/2" hole sections down to 1070 m. After setting the 13 3/8" casing the mud system was changed to a 1.27 SG KCL/ polymer system with 3 - 4 % glycol added for drilling the 12 1/4" and 8 1/2" sections to final TD. No shallow gas or boulder beds were encountered in the uppermost well section.The well penetrated mainly clays and claystones in the Nordland, Hordaland and Rogaland groups. Grid Formation sands were encountered from 1293 m to 1348 m and 1484 m to 1504 m. Minor thin distal remnants of the Heimdal Formation sands were encountered between 2050 and 2061.5 metres, however these proved water wet. Top Ty Formation was reached at 2157 m, consisting of clean sandstone divided by a thin shale bed. It continued down to top Shetland Group at 2209 metres. No hydrocarbons were found in the Ty Formation. The Shetland Group consisted mainly of chalk with the Cromer Knoll Group consisting of limestones interbedded with claystones and marls. The Hugin Formation sandstones came in at 2318 m and were found to be water bearing. Traces of dark brown tarry dead oil staining together with weak, dull yellow fluorescence and slight petroliferous odour was seen in the Heimdal Formation sands and claystones from 2050 m to 2061.5 m. Similarly traces of dark brown tarry dead oil stained grains were described at the top of the Hugin Formation at 2318 m and in a sidewall core recovered from 2315 m. Post well organic geochemical analysis performed by Geolab Nor indicates hydrocarbons, possibly locally migrated, occur throughout the Heimdal Formation interbedded sand and claystones section. Traces of migrated liquid hydrocarbons are present in the Ty Formation interval 2187 m - 2199 m with larger amounts detected in the Hugin Formation at around 2319 m and in the underlying Sleipner Formation sands, e.g. at 2333 m. Three cores were cut in the 8 1/2" hole section. Two cores, totalling 8.9 metres of sand and clay were cut in the Heimdal Formation and one 19.68 metre core was cut in excellent reservoir sands of the Hugin Formation.One FMT fluid sample was taken at 2105.5 m in the Våle Formation. The 10 l clean-up chamber was drained at well-site and contained only mud filtrate and formation water, the 4 l PVT chamber was sent onshore and flash to stock-tank conditions in laboratory gave gas and water with a gas/water ratio of 2.2 Sm3/Sm3. The gas gravity (air = 1) was 0.5956. The well was permanently abandoned as a well with shows on 12 August 1995.TestingNo drill stem test was performed. -
Borekaks i Sokkeldirektoratet
Borekaks i Sokkeldirektoratet Borekaks tilgjengelig for prøvetaking?YESBorekaks i Sokkeldirektoratet Borekaksprøve, topp dybde [m]Borekaksprøve, bunn dybde [m]1080.002378.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet12053.02053.7[m ]22053.02061.9[m ]32319.02338.7[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]29.3Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Kjernebilder
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Palynologiske preparater i Sokkeldirektoratet
Palynologiske preparater i Sokkeldirektoratet Prøve dybdeDybde enhetPrøve typeLaboratorie1750.5[m]SWCRRI1760.0[m]DCRRI1772.5[m]SWCRRI1780.0[m]DCRRI1794.5[m]SWCRRI1805.0[m]DCRRI1810.0[m]DCRRI1824.5[m]SWCRRI1830.5[m]SWCRRI1840.0[m]DCRRI1852.5[m]SWCRRI1860.0[m]DCRRI1875.5[m]SWCRRI1882.5[m]SWCRRI1900.0[m]DCRRI1916.5[m]SWCRRI1928.7[m]SWCRRI1941.0[m]DCRRI1950.0[m]DCRRI1959.0[m]DCRRI1968.0[m]DCRRI1980.0[m]DCRRI1992.0[m]DCRRI2000.0[m]DCRRI2010.0[m]DCRRI2022.0[m]SWCRRI2031.0[m]SWCRRI2037.0[m]DCRRI2048.5[m]SWCRRI2054.0[m]CRRI2054.5[m]SWCRRI2058.0[m]CRRI2061.0[m]DCRRI2061.9[m]CRRI2067.0[m]SWCRRI2082.0[m]DCRRI2093.0[m]SWCRRI2100.0[m]DCRRI2105.5[m]SWCRRI2121.0[m]DCRRI2130.0[m]SWCRRI2139.0[m]DCRRI2148.0[m]SWCRRI2156.0[m]SWCRRI2172.0[m]DCRRI2178.0[m]DCRRI2187.5[m]SWCRRI2199.0[m]DCRRI2211.0[m]SWCRRI2223.0[m]SWCRRI2230.0[m]DCRRI2230.0[m]DCRRI2240.0[m]DCRRI2245.0[m]DCRRI2250.0[m]DCRRI2260.0[m]DCRRI2268.0[m]SWCRRI2280.0[m]SWCRRI2290.0[m]DCRRI2299.0[m]SWCRRI2305.5[m]SWCRRI2310.0[m]DCRRI2318.0[m]SWCRRI2322.0[m]CRRI2326.0[m]CRRI2330.0[m]CRRI2330.0[m]DCRRI2331.3[m]CRRI2336.9[m]CRRI2338.7[m]CRRI2340.0[m]SWCRRI2354.0[m]SWCRRI2370.0[m]SWCRRI -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet1485779979971293134814841504190019001947203720502062207921572209220922672267228222932293229923182318232923402340 -
Geokjemisk informasjon
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Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk)
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk) Dokument navnDokument formatDokumentstørrelse [MB]pdf84.61 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]FMT HP GR00FMT HP GR20272160FMT HP GR20372338HEXDIP GR19922375MLL DLL DAC SL CAL10561932MLL DLL DAC SL CAL10561932MLL DLL MAC GR CAL19922379MWD - D-RAW148225MWD - D-RAW2251070MWD DPR-RAW10701411MWD DPR-RAW14112010MWD DPR-RAW20102053MWD DPR-RAW20532319MWD DPR-RAW23192380SWC GR12941928SWC GR20172370SWC GR20172370VSP9802230VSP22202360ZDL CN SL19922376 -
Foringsrør og formasjonsstyrketester
Foringsrør og formasjonsstyrketester Type utforingUtforing diam.
[tommer]Utforing dybde
[m]Brønnbane diam.
[tommer]Brønnbane dyp
[m]LOT/FIT slam eqv.
[g/cm3]Type formasjonstestCONDUCTOR30219.036220.00.00LOTSURF.COND.13 3/81057.017 1/21060.00.00LOTINTERM.9 5/81995.012 1/42000.00.00LOTOPEN HOLE2380.08 1/22380.00.00LOT -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling10741.2772.0WATER BASED14111.2762.0WATER BASED18551.2916.0WATER BASED20101.2952.0WATER BASED20421.2616.0WATER BASED20591.2649.0WATER BASED21861.2613.0WATER BASED23191.2646.0WATER BASED23411.2614.0WATER BASED23801.2614.0WATER BASED -
Tynnslip i Sokkeldirektoratet
Tynnslip i Sokkeldirektoratet DybdeEnhet2319.25[m ]2061.50[m ]2055.00[m ]2333.00[m ]2054.80[m ]2335.50[m ]2054.55[m ]2320.50[m ]2322.25[m ]2325.60[m ]2053.20[m ]2053.60[m ]2053.33[m ]2053.45[m ] -
Trykkplott
Trykkplott Porertrykksdataene kommer fra logging i brønnen hvis ingen annen kilde er oppgitt. I noen brønner der trykk ikke er logget, er det brukt informasjon fra formasjonstester eller brønnspark. Trykkdataene er rapportert inn til Oljedirektoratet og videre prosessert og kvalitetssikret av IHS Markit.Trykkplott Dokument navnDokument formatDokumentstørrelse [MB]pdf0.21