15/6-7
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Generell informasjon
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Brønnhistorie
GeneralWell 15/6-7 was the first well in licence 166. The primary objective of the well was to test the hydrocarbon potential of the Middle Jurassic, Hugin Formation of Callovian age within a seismically defined structural trap. There were no secondary objectives for the well, however, other potential reservoir horizons, albeit outside closure, were anticipated within the early Tertiary succession. The well programme was designed to maximize the evaluation of these sections asrequired.Operations and resultsExploration well 15/6-7 was spudded on 24 April 1993 with the semi-submersible installation "Vildkat Explorer" and drilled to TD at 3540 m in the Triassic Smith Bank Formation. The well was drilled with gel and seawater down to 505 m, with PHPA/KCl mud from 505 m to 1173 m, with PHPA/KCl/Glycol mud from 1173 m to 2788 m, and with PHPA/KCl mud from 2788 m to TD.The Quaternary and Tertiary sequence represented by the Nordland, Hordaland and Rogaland Group is dominated by mudstone lithologies with occasional thick sandstone developments in the Utsira, Grid, and Heimdal Formations. Background gas values ranged from less than 0.1% to 0.5% with rare isolated gas peaks. The Late Cretaceous succession in the well, 493 m thick, is dominated by carbonate lithologies of the Shetland Group; below 3150 m these become increasingly and atypically sandy. A number of gas peaks were recorded over the interval 3025 m to 3157 m with a maximum gas peak of 5.42% recorded at 3154 m. The Early Cretaceous, 14.5 m thick, represented by the Cromer Knoll Group is substantially thinner than anticipated and consists of arenaceous limestones interbedded with thin calcareous sandstones. The Upper Jurassic Draupne Formation was penetrated at 3233 m, 36 m low to prognosis. Intra Draupne Formation Sandstone was encountered at 3292 m. A formation fluid influx of 3.9 m3 equivalent to a calculated pore pressure of 1.5 sg (RFT) occurred at 3327 m (3331 m loggers depth), a gas peak of 0.74% was associated with this influx. The mud weight was increased from 1.30 sg to 1.52 sg during well control operations. The top Heather Formation was penetrated at 3352.5 m, 75.5 m deeper than anticipated. Background gas values within the Draupne and Heather Formations gradually decreased with depth from 4% to 0.18% at the base of the Heather Formation. The primary objective, the Hugin Formation, was penetrated at 3390.5 m, 4.5 m shallower than anticipated. The Hugin Formation consists of interbedded mudstones and sandstones with the sandstone beds increasing in thickness with depth. The well failed to penetrate any hydrocarbon bearing horizons. The primary objective Hugin Formation was water bearing. This was confirmed by RFT and petrophysical evaluation of the logs.One conventional core was cut over the interval 3414 m to 3432 m (15.7 m recovered) in the Triassic Skagerrak Formation. Three RFT runs, 3/1,3/2 and 3/3, were performed in the 8.5" hole section in the Draupne, Hugin and Skagerrak Formations, over the interval 3433-3331 m. A segregated sample was taken on run 3/3. The sample recovered 5 l of muddy water in the 6-gallon chamber. The 1-gallon chamber was plugged.The well was permanently plugged and abandoned as a dry hole on 8 June 1993.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]510.003540.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet13414.03429.7[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]15.7Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Kjernebilder
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Palynologiske preparater i Sokkeldirektoratet
Palynologiske preparater i Sokkeldirektoratet Prøve dybdeDybde enhetPrøve typeLaboratorie1700.0[m]SWCRRI1715.0[m]DCRRI1725.0[m]DCRRI1735.0[m]SWCRRI1750.0[m]SWCRRI1766.0[m]SWCRRI1780.0[m]DCRRI1795.0[m]DCRRI1805.0[m]DCRRI1822.0[m]SWCRRI1832.0[m]SWCRRI1862.0[m]SWCRRI1870.0[m]SWCRRI1880.0[m]DCRRI1889.0[m]SWCRRI1950.0[m]DCRRI1957.0[m]SWCRRI1965.0[m]DCRRI2022.0[m]SWCRRI2030.0[m]DCRRI2050.0[m]DCRRI2069.0[m]SWCRRI2109.0[m]SWCRRI2125.0[m]DCRRI2140.0[m]DCRRI2155.0[m]DCRRI2167.0[m]SWCRRI2183.0[m]SWCRRI2197.0[m]SWCRRI2215.0[m]DCRRI2230.0[m]DCRRI2269.0[m]SWCRRI2277.0[m]SWCRRI2290.0[m]DCRRI2297.0[m]SWCRRI2310.0[m]DCRRI2325.0[m]DCRRI2336.0[m]SWCRRI2350.0[m]DCRRI2360.0[m]DCRRI2370.0[m]SWCRRI2385.0[m]DCRRI2394.0[m]SWCRRI2425.0[m]DCRRI2440.0[m]DCRRI2463.0[m]SWCRRI2473.0[m]SWCRRI2490.0[m]DCRRI2505.0[m]DCRRI2530.0[m]DCRRI2537.0[m]SWCRRI2555.0[m]DCRRI2570.0[m]DCRRI2585.0[m]DCRRI2597.0[m]SWCRRI2607.0[m]SWCRRI2613.0[m]SWCRRI2625.0[m]DCRRI2640.0[m]DCRRI2650.0[m]DCRRI2660.0[m]SWCRRI2675.0[m]DCRRI3163.0[m]SWCRRI3175.0[m]SWCRRI3195.0[m]SWCRRI3209.5[m]SWCRRI3215.5[m]SWCRRI3236.0[m]SWCRRI3244.5[m]SWCRRI3257.0[m]SWCRRI3261.0[m]DCRRI3281.0[m]SWCRRI3291.5[m]SWCRRI3306.0[m]DCRRI3318.0[m]DCRRI3336.0[m]SWCRRI3354.0[m]DCRRI3374.0[m]SWCRRI3408.0[m]DCRRI3411.0[m]DCRRI3414.0[m]DCRRI3418.0[m]CRRI3420.7[m]CRRI3423.1[m]CRRI3429.7[m]CRRI -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet1327729931117123313071406183621082258225823022369242726062645267626762740298431883196321932193230323332333292335333913391341134113476 -
Spleisede logger
Spleisede logger Dokument navnDokument formatDokumentstørrelse [MB]pdf0.66 -
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]pdf35.51 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]CBL VDL GR CCL22822765CST GR13502602CST GR13722732CST GR30193525CST GR31563524DLL MSFL SDT AS AMS27753540DLL MSFL SDT AS GR4921152DLL MSFL SDT AS GR SP11572768LDL CNL NGS AMS11572764LDL CNL NGS AMS27753543MWD - BGD132505MWD - BGD GR5051173MWD - DPR28003146MWD - DPR34093536MWD - RDG32463410MWD - RGD11732788RFT33313433SHDT FMS GR AMS30983544SHDT GR AMS17002715VSP AMS10853515 -
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 formasjonstestCONDUCTOR30217.036220.00.00LOTINTERM.20492.026505.01.36LOTINTERM.13 3/81157.017 1/21173.01.84LOTINTERM.9 5/82773.012 1/42788.01.74LOTOPEN HOLE3540.08 1/23540.00.00LOT -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling1801.03WATER BASED2201.05WATER BASED5051.20WATER BASED11731.14190.0WATER BASED20671.30170.0WATER BASED21001.30180.0WATER BASED22131.30220.0WATER BASED24401.30180.0WATER BASED26141.30180.0WATER BASED26901.30190.0WATER BASED27001.30130.0WATER BASED27001.54230.0WATER BASED27881.30290.0WATER BASED31201.30180.0WATER BASED32261.50260.0WATER BASED34141.52200.0WATER BASED35401.52230.0WATER BASED -
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]pdf0.22