31/4-6
Eksport: PDF
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Generell informasjon
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Brønnhistorie
GeneralWell 31/4-6 was drilled on the Bjørgvin Arch in the Northern North Sea. The main objective was to appraise the 31/4-3 Discovery in the "Intra-Heather sand II" (Fensfjord Formation) and to define the oil/water contact.Operations and resultsAppraisal well 31/4-6 was spudded with the semi-submersible installation Nortrym on 28 February 1982 and drilled to TD at 2447 m in the Early Jurassic Drake Formation. No significant problem was encountered in the operations. The well was drilled with seawater and hi-vis sweeps down to 927 m, with non-dispersed Shale Trol mud from 927 m to 1865 m, and with a fully dispersed Lignosulphonate/Unical/Ligcon mud from 1865 m to TD.The Fensfjord Formation was encountered at 2150 m. It is a predominantly fine grained to silty, micaceous to very micaceous, subarcosic carbonaceous and occasionally glauconitic sandstone with a clay matrix and some heavily calcite cemented stringers. It is 89 m thick and oil bearing from 2156 m down to the OWC at 2172 m. Net pay in the oil bearing interval was 12.5 m with an average porosity of 26.4% and an average water saturation of 43.8%. As expected the overlying Sognefjord Formation seen in the 31/4-3 and 5 wells was not present at this location. Below the Heather Formation, the well penetrated 62.5 m of the Brent Group, which contained 31 m of net sand with an average porosity of 23.4% and was water saturated. No other reservoir intervals were encountered. Occasional poor oil shows were recorded in the Ness Formation and the Drake Formation.Five cores were cut through the Fensfjord Formation from 2132 m to 2214.5 m. Correlation between the cores and the logs indicates that core depths are two to three meters shallower than logger's depth. RFT fluid samples were taken in the Fensfjord Formation at 2160.5 m (oil and gas) and at 2166.5 m (oil and gas).The well was permanently abandoned on 20 April 1982as an oil appraisal.TestingOne production test was performed in the Fensfjord Formation over the combined intervals 2159.5 - 2163.5 m and 2165-2168 m. The well flowed 452 Sm3 oil and 38300 Sm3 gas through a 36/24" choke. The GOR was 85 Sm3/Sm3, the oil gravity was 34.4 deg API and the gas gravity was 0.727 (air = 1). Maximum flow temperature measured at sensor depth 2153.5 m was 90.6 deg C. -
Borekaks i Sokkeldirektoratet
Borekaks i Sokkeldirektoratet Borekaks tilgjengelig for prøvetaking?YESBorekaks i Sokkeldirektoratet Borekaksprøve, topp dybde [m]Borekaksprøve, bunn dybde [m]270.002447.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet12132.02148.3[m ]22149.02159.5[m ]32159.52178.0[m ]42178.12195.0[m ]52195.52214.0[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]80.7Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Kjernebilder
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Palynologiske preparater i Sokkeldirektoratet
Palynologiske preparater i Sokkeldirektoratet Prøve dybdeDybde enhetPrøve typeLaboratorie2035.0[m]SWCIKU2037.0[m]SWCIKU2043.0[m]SWCIKU2057.0[m]SWCIKU2060.0[m]SWCIKU2084.0[m]SWCIKU2090.0[m]SWCIKU2095.0[m]SWCIKU2100.0[m]SWCIKU2106.0[m]SWCIKU2109.0[m]SWCIKU2123.5[m]SWCIKU2128.0[m]SWCIKU2130.0[m]SWCIKU2132.0[m]CIKU2138.0[m]CIKU2144.4[m]CIKU2147.5[m]CIKU2149.5[m]CIKU2154.6[m]CIKU2156.5[m]CIKU2160.1[m]CIKU2170.5[m]CIKU2177.6[m]CIKU2183.1[m]CIKU2201.6[m]CIKU2208.8[m]CIKU2213.9[m]CIKU2215.0[m]SWCIKU2220.0[m]SWCIKU2225.0[m]SWCIKU2231.0[m]SWCIKU2237.0[m]SWCIKU2242.0[m]SWCIKU2247.0[m]SWCIKU2255.0[m]SWCIKU2262.0[m]SWCIKU2268.0[m]SWCIKU2274.0[m]SWCIKU2280.0[m]SWCIKU2287.0[m]SWCIKU2295.0[m]SWCIKU2303.0[m]SWCIKU2310.0[m]SWCIKU2321.0[m]SWCIKU2337.0[m]SWCIKU2345.0[m]SWCIKU2383.0[m]SWCIKU2387.0[m]SWCIKU2395.0[m]SWCIKU2405.0[m]SWCIKU2414.0[m]SWCIKU2416.0[m]SWCIKU2420.0[m]SWCIKU2425.0[m]SWCIKU2435.0[m]SWCIKU2448.0[m]SWCIKU -
Oljeprøver i Sokkeldirektoratet
Oljeprøver i Sokkeldirektoratet Test typeFlaske nummerTopp dyp
MD [m]Bunn dyp
MD [m]Væske typeTest tidspunktPrøver tilgjengeligDSTDST12159.002163.0014.04.1982 - 00:00YESDST0.000.00YES -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet155676854181018101876191120612109212321232136215023182318235623802380 -
Geokjemisk informasjon
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Dokumenter – eldre Sokkeldirektoratets WDSS rapporter og andre relaterte dokumenter
Dokumenter – eldre Sokkeldirektoratets WDSS rapporter og andre relaterte dokumenter Dokument navnDokument formatDokumentstørrelse [MB]pdf0.17pdf0.19 -
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk)
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk) Dokument navnDokument formatDokumentstørrelse [MB]pdf2.15PDF13.12 -
Borestrengtester (DST)
Borestrengtester (DST) Test nummerFra dybde MD
[m]Til dybde MD
[m]Reduksjonsventil størrelse
[mm]1.02159216314.3Borestrengtester (DST) Test nummerEndelig avstengningstrykk
[MPa]Endelig strømningstrykk
[MPa]Bunnhullstrykk
[MPa]Borehullstemperatur
[°C]1.0Borestrengtester (DST) Test nummerOlje produksjon
[Sm3/dag]Gass produksjon
[Sm3/dag]Oljetetthet
[g/cm3]Gasstyngde rel. luftGOR
[m3/m3]1.0452390000.8530.72785 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]CBL VDL7001840CST10201850CST20352310CST20652448DLL MSFL20352212FDC CNL18452215FDC GR9131862HDT18452446ISF SON1552214ISF SON NGT21152448LDT CNL EPT22152450RFT21382377RFT21602160RFT21662166VELOCITY3602444 -
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 formasjonstestCONDUCTOR30243.036243.50.00LOTSURF.COND.20913.026927.01.68LOTINTERM.13 3/81844.017 1/21865.01.72LOTINTERM.9 5/82406.012 1/42447.00.00LOT -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling2501.1132.0waterbased7601.1132.0waterbased9201.0341.0waterbased12401.1042.0waterbased17701.3463.0waterbased19401.2764.0waterbased21801.2854.0waterbased23101.3055.0waterbased24001.3154.0waterbased -
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]pdf0.18