34/4-8
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Generell informasjon
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Brønnhistorie
GeneralWell 34/4-8 is located on the "Beta Terrace", a down faulted terrace northwest of the Snorre Block in the central part of the block. The main objective of well 34/4-8 was to test the presence of hydrocarbons and the reservoir quality of the Statfjord Formation on the Beta Terrace. The well should also test the presence of hydrocarbons in the Lunde Formation, improve depth conversion and seismic tie for the pre-Cretaceous levels in this previously undrilled structural element, and give indications on further prospectivity north-westwards in block 34/4.Operations and resultsWildcat well 34/4-8 was spudded with the semi-submersible installation "Vildkat Explorer" on 22 May 1994 and drilled to TD at 3110 m in the Triassic Lunde Formation. Since possible shallow gas levels had been predicted, a 9 7/8" pilot hole was first drilled. No shallow gas was found. The well was drilled with spud mud and gel down to 1460 me and with KCl mud with a glycol additive from 1460 m to TD.The Nordland and Hordaland Groups were mainly silty claystones except for the sandy Utsira Formation, which came in at 1123 m. The Nordland and Hordaland Groups had a very high content of drilling gas (average 2-3%), but no signs of gas were seen on the logs. The Rogaland Group was penetrated at 1690 m, and consists of the Balder and Sele Formations. The Balder Formation was dominated by tuff interbedded with claystone. The Sele Formation consisted of silty claystones with traces of limestones. At 1838 m the Shetland Group was penetrated. The Shetland Group consisted predominantly of silty clay stone with some limestones and thin sandstone beds. The Cromer Knoll Group had marl as the main lithology. The marl was interbedded with silty claystones and sandstones. The Dunlin Group consisted of claystone interbedded with marl and minor sandstone beds. The Statfjord Formation was penetrated at 2799 m and consisted of sandstones alternating with shale/claystones. The Hegre Group proved to be generally alternating sandstones and claystones.Weak hydrocarbon shows were seen in the cuttings from 2210 m to 2490 m in the Shetland Group. The shows were seen in the sandstones and in the sandy parts of the claystones. There were bright yellow fluorescence, slow streaming moderate weak cut and yellow white residuum upon evaporation. No shows were seen in the sidewall cores. No hydrocarbons were found neither in the Statfjord nor the Lunde Formations. The only core attempted was in the Statfjord Formation but it jammed off and gave no recovery. No fluid samples were taken.The well was permanently abandoned as a dry well on 21 June 1994.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]510.003110.00 -
Palynologiske preparater i Sokkeldirektoratet
Palynologiske preparater i Sokkeldirektoratet Prøve dybdeDybde enhetPrøve typeLaboratorie1000.0[m]DC1020.0[m]DC1040.0[m]DC1060.0[m]DC1080.0[m]DC1100.0[m]DC1120.0[m]DC1140.0[m]DC1160.0[m]DC1180.0[m]DC1200.0[m]DC1220.0[m]DC1240.0[m]DC1260.0[m]DC1280.0[m]DC1310.0[m]DC1320.0[m]DC1340.0[m]DC1360.0[m]DC1380.0[m]DC1400.0[m]DC1420.0[m]DC1440.0[m]DC1460.0[m]DC1480.0[m]DC1500.0[m]DC1520.0[m]DC1540.0[m]DC1560.0[m]DC1580.0[m]DC1600.0[m]DC1620.0[m]DC1640.0[m]DC1660.0[m]DC1680.0[m]DC1700.0[m]DC1720.0[m]DC1740.0[m]DC1760.0[m]DC1780.0[m]DC1800.0[m]DC1820.0[m]DC1840.0[m]DC1860.0[m]DC1880.0[m]DC1900.0[m]DC1920.0[m]DC1940.0[m]DC1960.0[m]DC1980.0[m]DC2000.0[m]DC2020.0[m]DC2040.0[m]DC2060.0[m]DC2080.0[m]DC2100.0[m]DC2120.0[m]DC2140.0[m]DC2160.0[m]DC2420.0[m]DC2440.0[m]DC2460.0[m]DC2480.0[m]DC2500.0[m]DC2520.0[m]DC2540.0[m]DC2560.0[m]DC2580.0[m]DC2600.0[m]DC2620.0[m]DC2640.0[m]DC2665.0[m]DC2675.0[m]DC2685.0[m]DC2693.0[m]DC2700.0[m]DC2710.0[m]DC2720.0[m]DC2730.0[m]DC2740.0[m]DC2745.0[m]DC2755.0[m]DC2765.0[m]DC2774.0[m]DC2783.0[m]DC2792.0[m]DC2801.0[m]DC2919.0[m]DC2936.0[m]DC2945.0[m]DC2954.0[m]DC2963.0[m]DC2972.0[m]DC2981.0[m]DC2990.0[m]DC2999.0[m]DC3008.0[m]DC3017.0[m]DC3026.0[m]DC3035.0[m]DC -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet3881221123012381690169017201838183820702600276127612771279929132913 -
Spleisede logger
Spleisede logger Dokument navnDokument formatDokumentstørrelse [MB]pdf0.32 -
Geokjemisk informasjon
Geokjemisk informasjon Dokument navnDokument formatDokumentstørrelse [MB]pdf1.91 -
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk)
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk) Dokument navnDokument formatDokumentstørrelse [MB]pdf12.36 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]DPIL MAC ZDL CN DSL TTRM26503108DPIL MAC ZDL GR TTRM13342692FMT GR CHT28013080HDIP GR26813108MWD - DIR GR IND RES0499MWD - DIR GR IND RES14602693MWD - DIR GR IND RES26933108MWD - GR DPRS DIR4991460SWC GR15482572SWC GR26813108VSP26813108 -
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 formasjonstestCONDUCTOR30498.036500.00.00LOTSURF.COND.13 3/81445.017 1/21465.01.66LOTINTERM.9 5/82681.012 1/22693.01.86LOTOPEN HOLE3110.08 1/23110.00.00LOT -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling4351.5126.0DUMMY4991.12GEL MUD9961.1715.0GEL MUD14101.178.0GEL MUD14601.265.0GEL MUD20641.5930.0DUMMY21791.5927.0DUMMY23961.5934.0DUMMY24851.5929.0DUMMY26551.5930.0DUMMY26931.6032.0DUMMY27071.6028.0DUMMY27911.6227.0DUMMY29111.6227.0DUMMY31101.6223.0DUMMY -
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