16/2-10
Eksport: PDF
-
Generell informasjon
-
Brønnhistorie
GeneralWell 16/2-10 was drilled on the Utsira High in the North Sea to appraise the northern part of the Aldous Major Discovery in a segment called Espevær. The main objective was to investigate the hydrocarbon potential and thereservoir quality and lateral sand distribution in Late Jurassic sandstones in the Draupne Formation of the Viking Group, and the Hugin and Sleipner Formations of the Vestland Group. The secondary well objective was to explore the reservoir properties in the Triassic age Skagerrak Formation. The third objective was to investigate the hydrocarbon potential in the Cretaceous chalk of the Shetland Group.Operations and resultsA 9 7/8" pilot hole 16/2-U-6 was drilled to check for shallow gas down to setting depth for the 20" casing. No sign of shallow gas or shallow water flow was seen on the logs nor observed by the ROV.Appraisal well 16/2-10 was spudded with the semi-submersible installation Transocean Leader on 27 September 2011 and drilled to TD at 2090 m in the Late Triassic Skagerrak Formation. No significant problem was encountered in the operations. The well was drilled with sea water down to 463 m and with water based Performadril mud with 3-4% glycol from 463 m to TD.Well 16/2-10 penetrated sediments of Cenozoic, Cretaceous, Jurassic and Triassic age. Top of the Intra Draupne Formation sandstones, came in at 1892 m. An oil column of 66 meters was found in these sandstones and the underlying sandstones of the Middle Jurassic Hugin Formation. The free water level was established at 1957.7 m (1934.2 m TVD MSL) as confirmed by logs, cores, pressure data and fluid samples. This is deeper than in the 16/2-8 discovery well, where the free water level was found at 1920.7 m. The Triassic Skagerrak Formation was water wet. There were no sign of hydrocarbons in the Shetland Group. Oil shows were recorded from 1890 m to 1953 m.Four cores were cut from 1889.5 m in the Åsgard Formation to base Hugin Formation at 1962 m. Reservoir fluid samples were obtained in 3 MDT runs at 7 depths: 1893.5 m (oil), 1927.0 m (oil), 1935.5 m (oil), 1935.7 m (oil), 1955 m (oil and some water), 1961 m (water), and 1966 m (water).The well was permanently abandoned on 28 October 2011 as an oil appraisal well.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]460.002089.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet11889.51894.7[m ]21897.41912.5[m ]31912.51939.6[m ]41939.61962.0[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]69.9Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Palynologiske preparater i Sokkeldirektoratet
Palynologiske preparater i Sokkeldirektoratet Prøve dybdeDybde enhetPrøve typeLaboratorie460.0[m]DCFUGRO480.0[m]DCFUGRO500.0[m]DCFUGRO520.0[m]DCFUGRO540.0[m]DCFUGRO560.0[m]DCFUGRO580.0[m]DCFUGRO600.0[m]DCFUGRO620.0[m]DCFUGRO640.0[m]DCFUGRO660.0[m]DCFUGRO680.0[m]DCFUGRO700.0[m]DCFUGRO720.0[m]DCFUGRO740.0[m]DCFUGRO760.0[m]DCFUGRO780.0[m]DCFUGRO800.0[m]DCFUGRO820.0[m]DCFUGRO840.0[m]DCFUGRO860.0[m]DCFUGRO880.0[m]DCFUGRO900.0[m]DCFUGRO920.0[m]DCFUGRO940.0[m]DCFUGRO960.0[m]DCFUGRO980.0[m]DCFUGRO1000.0[m]DCFUGRO1020.0[m]DCFUGRO1040.0[m]DCFUGRO1060.0[m]DCFUGRO1080.0[m]DCFUGRO1100.0[m]DCFUGRO1120.0[m]DCFUGRO1140.0[m]DCFUGRO1160.0[m]DCFUGRO1180.0[m]DCFUGRO1200.0[m]DCFUGRO1220.0[m]DCFUGRO1240.0[m]DCFUGRO1260.0[m]DCFUGRO1280.0[m]DCFUGRO1300.0[m]DCFUGRO1320.0[m]DCFUGRO1340.0[m]DCFUGRO1360.0[m]DCFUGRO1390.0[m]DCFUGRO1400.0[m]DCFUGRO1420.0[m]DCFUGRO1440.0[m]DCFUGRO1460.0[m]DCFUGRO1480.0[m]DCFUGRO1500.0[m]DCFUGRO1520.0[m]DCFUGRO1540.0[m]DCFUGRO1560.0[m]DCFUGRO1580.0[m]DCFUGRO1600.0[m]DCFUGRO1620.0[m]DCFUGRO1633.0[m]DCFUGRO1639.0[m]DCFUGRO1657.0[m]DCFUGRO1729.0[m]DCFUGRO1747.0[m]DCFUGRO1759.0[m]DCFUGRO1765.0[m]DCFUGRO1771.0[m]DCFUGRO1777.0[m]DCFUGRO1783.0[m]DCFUGRO1789.0[m]DCFUGRO1795.0[m]DCFUGRO1801.0[m]DCFUGRO1807.0[m]DCFUGRO1813.0[m]DCFUGRO1819.0[m]DCFUGRO1825.0[m]DCFUGRO1831.0[m]DCFUGRO1837.0[m]DCFUGRO1882.0[m]DCFUGRO1885.0[m]DCFUGRO1888.0[m]DCFUGRO1898.6[m]CCFUGRO1904.2[m]CCFUGRO1906.6[m]CCFUGRO1911.2[m]CCFUGRO1922.0[m]CCFUGRO1928.9[m]CCFUGRO1929.9[m]CCFUGRO1930.1[m]CCFUGRO1931.0[m]CCFUGRO1940.0[m]CCFUGRO1944.9[m]CCFUGRO1948.1[m]CCFUGRO1952.6[m]CCFUGRO1959.0[m]CCFUGRO -
Oljeprøver i Sokkeldirektoratet
Oljeprøver i Sokkeldirektoratet Test typeFlaske nummerTopp dyp
MD [m]Bunn dyp
MD [m]Væske typeTest tidspunktPrøver tilgjengeligMDT1927.000.00OIL21.10.2011 - 00:00YESMDT1935.500.00OIL19.10.2011 - 00:00YESMDT1893.500.00OIL19.10.2011 - 00:00YES -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet1398181057108411371500150015311540160516221622163217101766178018091809185118851892189219241924196219681968 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]CMR ECS GR16312092FMI HNGS HRLA16312092LWD MWD - ARCRES6 ADN18892090LWD MWD - ARCRES8 PP138455LWD MWD - ARCRES9 TELE455948LWD MWD - GVR ARCRES8 TELE9481631LWD MWD - RAB6 ECO TELE16311889MDT HC18931966MDT PS18931966MDT QWS19551961MSIP GPIT PEX CBL10252078USIT GR12501630VSI4 GR12432082 -
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 formasjonstestCONDUCTOR30212.236213.00.00LOTSURF.COND.20449.026463.01.53LOTINTERM.13 3/8942.017 1/2948.00.00LOTINTERM.9 5/81630.012 1/41631.01.57LOTOPEN HOLE2090.08 1/22090.00.00LOT -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling1391.6024.0Kill Fluid- SW/Bentonite2161.6024.0Kill Fluid- SW/Bentonite3001.3522.0Spud Mud5131.2516.0Performadril8721.2526.0Performadril10451.3528.0Performadril16311.3751.0Performadril20901.2223.0Performadril -
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