2/3-4
Eksport: PDF
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Generell informasjon
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Brønnhistorie
GeneralWell 2/3-4 was drilled by Gulf Oil Corporation - Norway Branch as a non-obligatory well on behalf of the participants in Production Licence 022. All obligatory work had been previously been done. The well is situated 275 km SSW of Stavanger. Geologically, the location was chosen on the "Ula Trend" on the NE flank of the Central Graben in the southern Norwegian North Sea. The principal objective of the well was to test structural closure of Upper Jurassic Ula Formation sandstone. This formation was believed to exist within 100 m below the nearest representative mappable seismic reflection, the Base Cretaceous Unconformity. The well was also planned to penetrate an Oligocene sand down-dip from a very small gas accumulation defined by a seismic flat spot anomaly, and which was therefore believed to be water wet at the location. The chalk reservoir was not predicted to be hydrocarbon bearing, nor was the well located within its mapped closure.Operations and resultsExploration well 2/3-4 was spudded with the jack-up installation Glomar Moray Firth I on 28 may 1984 and drilled to a total depth of 3386.3 m in Permian (Zechstein) evaporites. The well was drilled with seawater and gel down to 651 m and with Safemul oil based mud from 651 m to TD. Some swelling of the Miocene clay occurred during drilling of the 17 1/2" hole, otherwise no major problems occurred. Well 2/3-4 was the first exploration well for which NPD approved that conventional wire line logs was replaced with a suite of MWD logs.The primary objective, Ula Formation sands, was penetrated at 3006 m and was 207 m thick. The porosity of particularly the uppermost 170 m was excellent, generally between 25% and 30%. Electric logs, and a formation fluid sample (from FMT), indicated that the reservoir was water bearing throughout. Shows detection was made difficult due to the mud used. However, spectrofluorometric analyses on cuttings samples while drilling indicated that real shows could be present in the interval between 3045 m and 3006 m. The formation pressure gradient of 1.51 psi/m (0.46 psi/ft) within the reservoir further confirmed that the pore fluid was water, and that no vertical permeability barriers were present. Two segregated FMT samples were taken at 3011.5 m and 3073 m, both contained water. One core was cut from 3125.3 m to 3144.3 m in the Ula Formation sandstone. An anomalous high gamma ray peak was observed at 3030.6 m. The well was permanently abandoned as a dry well on 24 July 1984.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]200.003386.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet13125.43144.0[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]18.6Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Kjernebilder
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Palynologiske preparater i Sokkeldirektoratet
Palynologiske preparater i Sokkeldirektoratet Prøve dybdeDybde enhetPrøve typeLaboratorie1400.0[m]DCRRI1450.0[m]DCRRI1500.0[m]DCRRI1550.0[m]DCRRI1600.0[m]DCRRI1650.0[m]DCRRI1700.0[m]DCRRI1710.0[m]DCRRI1720.0[m]DCRRI1740.0[m]DCRRI1750.0[m]DCRRI1780.0[m]DCRRI1790.0[m]DCRRI1810.0[m]DCRRI1820.0[m]DCRRI1830.0[m]DCRRI1840.0[m]DCRRI1850.0[m]DCRRI1870.0[m]DCRRI1880.0[m]DCRRI1900.0[m]DCRRI1905.0[m]DCRRI1915.0[m]DCRRI1920.0[m]DCRRI1930.0[m]DCRRI1945.0[m]DCRRI1950.0[m]DCRRI1960.0[m]DCRRI1970.0[m]DCRRI1975.0[m]DCRRI1990.0[m]DCRRI2005.0[m]DCRRI2020.0[m]DCRRI2035.0[m]DCRRI2050.0[m]DCRRI2060.0[m]DCRRI2065.0[m]DCRRI2080.0[m]DCRRI2095.0[m]DCRRI2105.0[m]DCRRI2110.0[m]DCRRI2125.0[m]DCRRI2140.0[m]DCRRI2155.0[m]DCRRI2160.0[m]DCRRI2170.0[m]DCRRI2185.0[m]DCRRI2190.0[m]DCRRI2200.0[m]DCRRI2215.0[m]DCRRI2230.0[m]DCRRI2245.0[m]DCRRI2260.0[m]DCRRI2270.0[m]DCRRI2275.0[m]DCRRI2290.0[m]DCRRI2300.0[m]DCRRI2305.0[m]DCRRI2320.0[m]DCRRI2335.0[m]DCRRI2350.0[m]DCRRI2365.0[m]DCRRI2380.0[m]DCRRI2395.0[m]DCRRI2400.0[m]DCRRI2410.0[m]DCRRI2425.0[m]DCRRI2440.0[m]DCRRI2450.0[m]DCRRI2455.0[m]DCRRI2470.0[m]DCRRI2485.0[m]DCRRI2500.0[m]DCRRI2505.0[m]DCRRI2515.0[m]DCRRI2525.0[m]DCRRI2530.0[m]DCRRI2535.0[m]DCRRI2545.0[m]DCRRI2560.0[m]DCRRI2575.0[m]DCRRI2590.0[m]DCRRI2600.0[m]DCRRI2605.0[m]DCRRI2610.0[m]DCRRI2620.0[m]DCRRI2650.0[m]DCRRI2660.0[m]DCRRI2670.0[m]DCRRI2675.0[m]DCRRI2680.0[m]DCRRI2690.0[m]DCRRI2695.0[m]DCRRI2710.0[m]DCRRI2785.0[m]DCRRI2800.0[m]DCRRI3000.0[m]DCRRI3006.0[m]DCRRI3034.0[m]DCRRI3060.0[m]DCRRI3113.0[m]DCRRI3135.5[m]DCRRI3142.0[m]DCRRI3144.0[m]DCRRI3180.0[m]DCRRI3188.0[m]DCRRI3204.0[m]DCRRI3236.0[m]DCRRI3248.0[m]DCRRI3256.0[m]DCRRI3268.0[m]DCRRI3302.0[m]DCRRI3322.0[m]DCRRI3334.0[m]DCRRI3342.0[m]DCRRI -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet9614342527252725482592261327192719279629252925293030053005300630063215333233323377 -
Spleisede logger
Spleisede logger Dokument navnDokument formatDokumentstørrelse [MB]pdf0.52 -
Geokjemisk informasjon
Geokjemisk informasjon Dokument navnDokument formatDokumentstørrelse [MB]pdf0.40 -
Dokumenter – eldre Sokkeldirektoratets WDSS rapporter og andre relaterte dokumenter
Dokumenter – eldre Sokkeldirektoratets WDSS rapporter og andre relaterte dokumenter Dokument navnDokument formatDokumentstørrelse [MB]pdf0.21pdf0.30 -
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk)
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk) Dokument navnDokument formatDokumentstørrelse [MB]pdf1.98pdf23.56 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]DIFL ACL CDL CN GR CAL16852965DIFL ACL CDL CN GR CAL29593139DIFL ACL CDL CN GR CAL30603381DIFL ACL CDL GR CAL6111764DIPLOG29593382FMT00MWD - GR6441780MWD - GR18282959MWD - GR RES195644TEMP20620TEMP5002940VELOCITY6113381VSP16003370XY CAL GR157648 -
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 formasjonstestCONDUCTOR30183.536335.30.00LOTSURF.COND.20644.526650.51.49LOTINTERM.13 3/81770.617 1/21786.01.74LOTINTERM.9 5/82963.912 1/42967.81.92LOTOPEN HOLE3386.08 1/23386.00.00LOT -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling1281.43WATER BASED29.05.19842011.32WATER BASED31.05.19842011.32WATER BASED31.05.19842011.04WATER BASED04.06.19846391.14330.0200.0OIL BASED15.06.19846511.056.029.0WATER BASED05.06.198412131.2631.022.0OIL BASED17.06.198417711.3837.025.0OIL BASED25.06.198421571.4032.025.0OIL BASED28.06.198425631.4139.027.0OIL BASED02.07.198427951.4134.011.1OIL BASED04.07.198428891.4132.010.6OIL BASED04.07.198429681.4935.015.4OIL BASED06.07.198430011.5336.014.9OIL BASED11.07.198431251.5636.014.9OIL BASED13.07.1984 -
Tynnslip i Sokkeldirektoratet
Tynnslip i Sokkeldirektoratet DybdeEnhet3136.00[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]pdf0.23