6507/8-1
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Generell informasjon
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Brønnhistorie
GeneralWell 6507/8-1 was drilled on the eastern part of the Heidrun Discovery. The primary objective was to ascertain that the Heidrun field extension into the 6507/8 block and to verify reserve calculations. Secondary objectives were to verify geological model and structural interpretation, and define oil water contact in the Tilje Formation. It was also intended to provide more information on reservoir characteristics and hydrocarbon fluids, and maximum input of data for reservoir simulation studies. The Fangst Group was expected at 2245 m, and the Tilje Formation at 2340 m. Prognosed TD was 2590 m.Operations and resultsWildcat well 6507/8-1 was spudded with the semi-submersible installation Dyvi Delta on and drilled to TD at 2600 m in Early Jurassic sediments of the Åre Formation. Drilling proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 1063 m, with KCl/polymer mud from 1063 m to 2235 m, and with gel/polymer/lingo mud from 2235 m to TD.The only oil shows reported above the target reservoir were on sandstone in a cuttings sample at 2235, and on limestone in a SWC at 2238 m, both samples from the Melke Formation. The Middle Jurassic Fangst Group was penetrated at 2248 m and the Early Jurassic Tilje Formation at 2386.5 m. These reservoir sandstones were found to be hydrocarbon bearing with a gas/oil contact at 2312 m and an oil/water contact at 2480 m.A total of 9 cores were cut from 2249 m to 2469 m in the Garn, Not, Ile, Ror, and Tilje Formations. Core no 1 from the Garn Formation was loose sand and was lost on the drill floor while recovering from core barrel. One relatively good RFT fluid sample was taken at 2317 m. It contained oil with a density of 0.88 g/cc (29 deg API).The well was permanently abandoned on 9 December 1986 as a gas and oil appraisal.TestingTwo DST tests were performed in the Tilje Formation.DST 1 tested the interval 2444 - 2463 m and produced 715 Sm3 oil and 31460 Sm3 gas /day through a 3.81 cm choke. The GOR was 44 Sm3/Sm3, the stock tank oil gravity was 0.933 g/cm3 (22.8 deg API), and the gas gravity was 0.600 (air=1). This test produced no sand.DST 2 tested the interval 2386.4 -2405.4 m and produced 906 Sm3 oil and 50080 Sm3 gas /day through a 1.91 cm choke. The GOR was 55 Sm3/Sm3, the stock tank oil gravity was 0.917 g/cm3 (22.8 deg API), and the gas gravity was 0.615 (air=1) with 0.5 ppm H2S and 1.5 % CO2. This test also produced some sand. The down-hole temperatures recorded during the tests were 84.9 and 81 deg C in DST 1 and DST 2, respectively. -
Borekaks i Sokkeldirektoratet
Borekaks i Sokkeldirektoratet Borekaks tilgjengelig for prøvetaking?YESBorekaks i Sokkeldirektoratet Borekaksprøve, topp dybde [m]Borekaksprøve, bunn dybde [m]1050.002600.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet22262.02272.3[m ]32290.02314.5[m ]42316.02343.9[m ]52369.02386.9[m ]62398.02411.6[m ]72417.02434.3[m ]82439.02466.9[m ]92467.02494.8[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]167.1Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Kjernebilder
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Oljeprøver i Sokkeldirektoratet
Oljeprøver i Sokkeldirektoratet Test typeFlaske nummerTopp dyp
MD [m]Bunn dyp
MD [m]Væske typeTest tidspunktPrøver tilgjengeligDSTDST12444.002462.5030.11.1986 - 00:00YESDSTDST22386.002406.0004.12.1986 - 00:00YES -
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 formasjonstestCONDUCTOR30444.036610.00.00LOTINTERM.13 3/81033.017 1/21050.01.64LOTINTERM.9 5/82217.012 1/42235.01.60LOTLINER72598.58 1/22600.00.00LOT -
Borestrengtester (DST)
Borestrengtester (DST) Test nummerFra dybde MD
[m]Til dybde MD
[m]Reduksjonsventil størrelse
[mm]1.02444246338.12.02386240619.1Borestrengtester (DST) Test nummerEndelig avstengningstrykk
[MPa]Endelig strømningstrykk
[MPa]Bunnhullstrykk
[MPa]Borehullstemperatur
[°C]1.03.0002.00017.000852.06.0005.00081Borestrengtester (DST) Test nummerOlje produksjon
[Sm3/dag]Gass produksjon
[Sm3/dag]Oljetetthet
[g/cm3]Gasstyngde rel. luftGOR
[m3/m3]1.0715314600.9320.600442.0906500800.92555 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]CBL VDL GR9002214CBL VDL GR20632552CBL VDL GR22402421CST GR22322241DITE SDT GR22172596DLL MSFL GR22172591LDL CNL GR22172600MWD - GR RES DIR3712600NGS22172600RFT22502580RFT HP GR22502580RLL10332600SDT GR11852217SHDT GR22172600VELOCITY10002600 -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet37114621885188519701970202020602233223322482248229423072324232423872559 -
Geokjemisk informasjon
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Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk)
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk) Dokument navnDokument formatDokument størrelse [KB]pdf9.60pdf1.73 -
Dokumenter – eldre Sokkeldirektoratets WDSS rapporter og andre relaterte dokumenter
Dokumenter – eldre Sokkeldirektoratets WDSS rapporter og andre relaterte dokumenter Dokument navnDokument formatDokument størrelse [KB]pdf0.25pdf0.20 -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling10531.126200.06.8WATER BASED04.11.198613981.146300.05.9WATER BASED05.11.198616751.356000.06.3WATER BASED06.11.198617001.355100.04.7WATER BASED10.11.198621311.355500.05.9WATER BASED07.11.198622171.209999.06.3WATER BASED12.11.198622171.219999.06.3WATER BASED17.11.198622171.209500.05.5WATER BASED18.11.198622171.206.3WATER BASED19.11.198622171.202000.04.2WATER BASED24.11.198622171.201500.04.7WATER BASED24.11.198622170.001200.03.5WATERBASED27.11.198622171.203900.03.0WATER BASED28.11.198622171.209000.05.5WATER BASED13.11.198622171.209999.06.3WATER BASED14.11.198622171.209500.05.9WATER BASED17.11.198622170.001500.03.4WATERBASED25.11.198622170.001400.03.8WATERBASED26.11.198622351.355000.03.8WATER BASED10.11.198622621.203600.06.8WATER BASED11.11.1986 -
Palynologiske preparater i Sokkeldirektoratet
Palynologiske preparater i Sokkeldirektoratet Prøve dybdeDybde enhetPrøve typeLaboratorie1700.0[m]DCSTATO1730.0[m]DCSTATO1740.0[m]DCSTATO1760.0[m]DCSTATO1770.0[m]DCSTATO1790.0[m]DCSTATO1800.0[m]DCSTATO1820.0[m]DCSTATO1830.0[m]DCSTATO1850.0[m]DCSTATO1860.0[m]DCSTATO1880.0[m]DCSTATO1890.0[m]DCSTATO1910.0[m]DCSTATO1920.0[m]DCSTATO1940.0[m]DCSTATO1950.0[m]DCSTATO1970.0[m]DCSTATO1980.0[m]DCSTATO2000.0[m]DCSTATO2010.0[m]DCSTATO2030.0[m]DCSTATO2040.0[m]DCSTATO2060.0[m]DCSTATO2070.0[m]DCSTATO2090.0[m]DCSTATO2100.0[m]DCSTATO2120.0[m]DCSTATO2130.0[m]DCSTATO2150.0[m]DCSTATO2160.0[m]DCSTATO2180.0[m]DCSTATO2190.0[m]DCSTATO2210.0[m]DCSTATO2220.0[m]DCSTATO2223.0[m]SWCSTATO2227.0[m]SWCSTATO2234.0[m]SWCSTATO2239.0[m]SWCSTATO2244.0[m]SWCSTATO2247.0[m]SWCSTATO2266.0[m]SWCSTATO2271.4[m]CSTATO2298.6[m]CSTATO2305.8[m]CSTATO2323.1[m]CSTATO2343.7[m]CSTATO2350.0[m]DCSTATO2361.0[m]DCSTATO2372.2[m]CSTATO2383.6[m]CSTATO2398.5[m]CSTATO2403.8[m]CSTATO2418.9[m]CSTATO2426.5[m]CSTATO2444.4[m]CSTATO2454.7[m]CSTATO2463.8[m]CSTATO2477.8[m]CSTATO2489.5[m]CSTATO2499.0[m]DCSTATO2505.0[m]DCSTATO2511.0[m]DCSTATO2517.0[m]DCSTATO2529.0[m]DCSTATO2535.0[m]DCSTATO2541.0[m]DCSTATO2553.0[m]DCSTATO2565.0[m]DCSTATO2577.0[m]DCSTATO2595.0[m]DCSTATO2600.0[m]DCSTATO