24/9-3
Eksport: PDF
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Generell informasjon
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Brønnhistorie
GeneralExploration well 24/9-3 was drilled by Conoco for the Conoco/Statoil/Norsk Hydro/Hudbay PL 039 partnership. The well lies in the west-central part of block 24/9, close to the Norway/UK median line. The location was chosen to test an apparent sand build-up, observable on seismic lines, in the Lower Tertiary part of the section. The sand build-up was thought to correspond to the Lower Eocene Frigg Sand Formation, which forms the reservoir in the Frigg Field.Operations and resultsWell 24/9-3 was spudded with the semi-submersible installation SEDCO 704 on 28 January 1981 and drilled to TD at 3051 m in the Late Cretaceous Jorsalfare Formation. The duration of the well was 81 days, 20 of which were spent testing. A 36" hole was drilled to 207.6 m / 681 ft and 30" casing set to same depth. A 17 1/2" pilot hole was drilled to 518.2 m, logged, and then opened to 26". 20" x-56 casing was set at 503.2 m. A 17 1/2" hole was drilled to 1600.2 m, logged, and 13 3/8" N-80 casing was set at 1587.1 m. A 12 1/4" hole was drilled and cored to 2049.8 m, logged, and 9 5/8" N-80 casing was set then drilled to TD and logged. The well was drilled with spud mud to 518 m, with Dextrid/gel from 518 m to 853 m, with gel/lime from 853 m to 1067 m, with seawater/gel/Dextrid from 1067 m to 1600 m, and with seawater/lime/Dextrid mud from 1600 m to TD.The Lower Eocene sands (Frigg Formation) were encountered 141 m high to prognosis at 1739 m. This shows that the sands correspond to a higher and less distinct build-up on the seismic. The build-up originally mapped corresponded to the Paleocene Tuff level and contained shales and water-wet Paleocene Sands. A gross interval of 92 m of Early Eocene Sands was penetrated. The uppermost 70 m, from 1739 m, were hydrocarbon bearing down to an OWC at 1809 m, while the lowermost 22 m (1809-1831m) were water bearing. Patchy oil shows were observed down to 1870 m, no shows were recorded below this depth. Core analysis carried out by Geco indicated residual oil saturations of 13.4 % - 32.4 % and that the sands, where present, were of excellent reservoir quality with porosities of up to 39% and permeabilities in the 2-4 Darcy range.A single RFT result and the results of DST3 in the upper part of the Frigg Formation reservoir (1739.5 m û1747 m) combine to indicate the possibility that a gas zone existed in the interval 1739 m (Top Sand) - 1765m. There is, however, no indication of gas on the logs and the poor results from DST3 suggested that the zone tested was essentially tight.Bubble point measurements carried out at well site and subsequently confirmed in the laboratory by Flopetrol showed that the crude in the proven oil zone is under saturated. It therefore follows that the gas zone, if present, represents a separate accumulation and is not in pressure contact with the oil zone.Five cores were cut in the interval 1777.9 m to 1797.7 m in the Early Eocene sands. The core depths were generally ca 5 m deep to logger's depth. Geochemical samples were taken at 30 m intervals from 13 3/8" casing to TD.The well was permanently abandoned as an oil discovery on 15 April 1981.TestingAfter logging at TD the well was plugged back to 1995.5 m and three zones were tested using prepacked screens and a coiled tubing nitrogen unit for artificial lift. Three drill-stem tests were carried out on the hydrocarbon interval. Tests 1 (1797 m to 1805 m) and 2 (1765.4 m to 1773 m) in the lower part of the reservoir produced 21.5 - 23¦ API oil at rates 39 Sm3 oil/day and 86 Sm3 oil/day, respectively. Test 3 in the uppermost part of the reservoir gave only a small trickle of gas. -
Borekaks i Sokkeldirektoratet
Borekaks i Sokkeldirektoratet Borekaks tilgjengelig for prøvetaking?NOBorekaks i Sokkeldirektoratet Borekaksprøve, topp dybde [m]Borekaksprøve, bunn dybde [m]210.002959.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet11777.91780.8[m ]21783.41787.0[m ]31788.01788.6[m ]41788.91794.6[m ]51794.61797.2[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]15.5Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Kjernebilder
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Palynologiske preparater i Sokkeldirektoratet
Palynologiske preparater i Sokkeldirektoratet Prøve dybdeDybde enhetPrøve typeLaboratorie1590.0[m]DCPSER1611.0[m]SWCPSER1625.0[m]SWCPSER1633.0[m]DCPSER1655.5[m]SWCPSER1663.0[m]DCPSER1686.0[m]SWCPSER1693.0[m]DCPSER1719.0[m]SWCPSER1723.0[m]DCPSER1739.0[m]SWCPSER1750.0[m]DCPSER1766.5[m]SWCPSER1778.0[m]SWCPSER1779.7[m]CPSER1783.0[m]DCPSER1784.3[m]CPSER1797.0[m]CPSER1810.0[m]SWCPSER1844.0[m]SWCPSER1855.0[m]DCPSER1867.5[m]SWCPSER1873.0[m]DCPSER1894.0[m]SWCPSER1903.0[m]DCPSER1921.0[m]SWCPSER1933.0[m]DCPSER1948.0[m]DCPSER1963.0[m]DCPSER1978.0[m]DCPSER1993.0[m]DCPSER1995.0[m]SWCPSER2008.0[m]DCPSER2018.0[m]SWCPSER2023.0[m]DCPSER2038.0[m]DCPSER2053.0[m]DCPSER2068.0[m]SWCPSER2077.0[m]DCPSER2098.0[m]DCPSER2113.0[m]DCPSER2118.0[m]DCPSER2128.0[m]DCPSER2144.0[m]SWCPSER2158.0[m]DCPSER2176.0[m]DCPSER2188.0[m]DCPSER2203.0[m]DCPSER2233.0[m]DCPSER2248.0[m]DCPSER2263.0[m]DCPSER2278.0[m]DCPSER2293.0[m]DCPSER2308.0[m]DCPSER2325.0[m]SWCPSER2329.0[m]DCPSER2338.0[m]DCPSER2353.0[m]DCPSER2368.0[m]DCPSER2386.0[m]DCPSER2398.0[m]DCPSER2413.0[m]DCPSER2436.0[m]SWCPSER2443.0[m]DCPSER2458.0[m]DCPSER2473.0[m]DCPSER2491.0[m]DCPSER2503.0[m]DCPSER2518.0[m]DCPSER2533.0[m]DCPSER2544.0[m]DCPSER2563.0[m]DCPSER2578.0[m]DCPSER2595.0[m]SWCPSER2608.0[m]DCPSER2627.0[m]SWCPSER2638.0[m]DCPSER2653.0[m]DCPSER2668.0[m]DCPSER2683.0[m]DCPSER2698.0[m]DCPSER2716.0[m]DCPSER2737.0[m]DCPSER2749.0[m]SWCPSER2761.0[m]DCPSER2773.0[m]DCPSER2788.0[m]DCPSER2803.0[m]DCPSER2825.0[m]SWCPSER2830.0[m]DCPSER -
Oljeprøver i Sokkeldirektoratet
Oljeprøver i Sokkeldirektoratet Test typeFlaske nummerTopp dyp
MD [m]Bunn dyp
MD [m]Væske typeTest tidspunktPrøver tilgjengeligDST11796.001805.00OIL21.03.1981 - 00:00YESDST1764.401782.2001.04.1981 - 00:00YES -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet1453606406406961201140017391831191819181981206022152567275728362836 -
Spleisede logger
Spleisede logger Dokument navnDokument formatDokumentstørrelse [MB]pdf0.42 -
Geokjemisk informasjon
Geokjemisk informasjon Dokument navnDokument formatDokumentstørrelse [MB]pdf0.56 -
Dokumenter – eldre Sokkeldirektoratets WDSS rapporter og andre relaterte dokumenter
Dokumenter – eldre Sokkeldirektoratets WDSS rapporter og andre relaterte dokumenter Dokument navnDokument formatDokumentstørrelse [MB]pdf0.10pdf0.25 -
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk)
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk) Dokument navnDokument formatDokumentstørrelse [MB]pdf54.09 -
Borestrengtester (DST)
Borestrengtester (DST) Test nummerFra dybde MD
[m]Til dybde MD
[m]Reduksjonsventil størrelse
[mm]1.0180517960.02.01782177550.83.0174717390.0Borestrengtester (DST) Test nummerEndelig avstengningstrykk
[MPa]Endelig strømningstrykk
[MPa]Bunnhullstrykk
[MPa]Borehullstemperatur
[°C]1.02.03.0Borestrengtester (DST) Test nummerOlje produksjon
[Sm3/dag]Gass produksjon
[Sm3/dag]Oljetetthet
[g/cm3]Gasstyngde rel. luftGOR
[m3/m3]1.03910000.9160.650262.08624000.9250.630283.010000.562 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]CBL VDL CNL CCL GR9702036CST16111995CST20483020DDBHC GR17191925DLL MSFL GR SP15842033FDC CNL GR CAL15833042HDT CAL15843035ISF DDBHC GR SP5142037ISF DDBHC GR SP19163041RFT17541802VSP3483030 -
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 formasjonstestCONDUCTOR30207.636207.60.00LOTSURF.COND.20503.226518.21.38LOTINTERM.13 3/81587.117 1/21600.21.64LOTINTERM.9 5/83051.012 1/43051.00.00LOT -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling4501.14200.0spud mud8601.0450.0water based12901.1164.0water based14901.1187.0water based17701.2348.0water based19101.3255.0water based22401.3150.0water based25501.2555.0water based27201.2562.0water based29301.2057.0water 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