34/7-7
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Generell informasjon
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Brønnhistorie
GeneralWell 34/7-7 was drilled on the western side of the “Inner Main Fault” near the geographic centre of the Snorre Field. The objectives were to test the reservoir quality of the Statfjord Group and the Oil-Water Contact, expected to be at 2611 m. Further objectives were to test the subdivision and reservoir characteristics of the Triassic Lunde Formation.Operations and resultsWildcat well 34/7-7 was spudded with the semi-submersible installation Treasure Saga on 17 September 1985 and drilled to TD at 3526 m in the Late Triassic Lunde Formation. A 17 1/2” pilot hole was drilled from 455 m to 995 m to check for shallow gas before opening up to 26”. No shallow gas was seen. Some fishing jobs were required during logging and testing, otherwise operations proceeded without significant problems. The well was drilled with spud mud down to 455 m, with gel mud from 455 m to 995 m, with gypsum/polymer mud from 995 m to 2562 m, and with gel mud from 2562 m to TD.Well 34/7-7 penetrated top reservoir at 2561.1 m. The OWC was defined at 2615 m in the Statfjord Group. The average log porosity in the oil zone is 26.2%, the net/gross is 0.37, and the average water saturation is 26.2%. Weak oil shows were seen from around 2140 m in sandstone and siltstone from early Campanian in the Shetland Group (top Kyrre Formation) and down to to the top Dunlin Group at 2455 m. Through the Dunlin Group down to the top Statfjord reservoir at 2561 m, the shows became stronger. Below the OWC, a sandstone interval at the bottom of the Statfjord (2640 - 2644 m) had good oil shows. Going into the Upper Lunde, the shows disappear.Nineteen cores were cut and recovered during drilling of the well. Core 1 to 8 were cut from 2563 to 2669.5 m through the whole Statfjord Group and the first meters of the Upper Lunde Formation. Core 9 to 19 were cut in the interval 2888.2 to 3336.7 m in the Upper Lunde Formation. Total core recovery was 197.25 m (94.1%). The core - log depth shifts for the individual cores varied from -0.6 m to +1.8 m. FMT oil samples were taken at 2613.5 m and 2564.8 m.The well was permanently abandoned on 16 December as an oil appraisal well.TestingTwo Drill Stem Tests (DST) were carried out in the Statfjord Group, Eiriksson Formation.DST 1 tested the interval 2561.5-2569.5 m at the top of the oil zone. The test produced 1720 Sm3 oil /day through a 14.3 mm choke. At stock tank conditions the GOR was 68 Sm3/Sm3, the oil density was 0.8362 g/cm3, and the gas gravity was 1.059 (air = 1). The bottom hole temperature was 93 °C.DST 2 tested the interval 2611.7-2614.7 m just above the OWC. The test produced 980 Sm3 oil /day through a 71.8 mm choke. At stock tank conditions the GOR was 62.5 Sm3/Sm3, the oil density was 0.8403 g/cm3, and the gas gravity was 1.081 (air = 1). The bottom hole temperature was 93 °C. -
Borekaks i Sokkeldirektoratet
Borekaks i Sokkeldirektoratet Borekaks tilgjengelig for prøvetaking?YESBorekaks i Sokkeldirektoratet Borekaksprøve, topp dybde [m]Borekaksprøve, bunn dybde [m]460.003526.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet12562.02568.0[m ]22569.02574.8[m ]32585.02593.5[m ]42593.52613.0[m ]52614.02623.3[m ]62624.02635.3[m ]72635.52655.0[m ]82656.02667.7[m ]92877.02886.4[m ]102886.42895.7[m ]112895.72905.0[m ]122905.02913.5[m ]132913.72923.1[m ]142923.12932.3[m ]152932.42941.6[m ]162941.62950.8[m ]172951.12963.8[m ]183320.03328.5[m ]193329.03337.5[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]194.7Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Kjernebilder
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Palynologiske preparater i Sokkeldirektoratet
Palynologiske preparater i Sokkeldirektoratet Prøve dybdeDybde enhetPrøve typeLaboratorie2443.0[m]SWCR.R.I2457.0[m]SWCR.R.I2515.0[m]SWCR.R.I -
Oljeprøver i Sokkeldirektoratet
Oljeprøver i Sokkeldirektoratet Test typeFlaske nummerTopp dyp
MD [m]Bunn dyp
MD [m]Væske typeTest tidspunktPrøver tilgjengeligDSTDST12561.502569.50OIL13.11.1985 - 15:00YESDSTDST1,10.000.00OIL23.11.1985 - 00:00YESDSTTEST22611.002614.00OIL08.12.1985 - 00:00YES -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet3299681068114711471678167816931793183718372139244524452455245525602560262926782678 -
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]pdf0.31pdf0.25 -
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk)
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk) Dokument navnDokument formatDokumentstørrelse [MB]pdf3.90pdf19.56 -
Borestrengtester (DST)
Borestrengtester (DST) Test nummerFra dybde MD
[m]Til dybde MD
[m]Reduksjonsventil størrelse
[mm]1.02562257014.32.02615261217.5Borestrengtester (DST) Test nummerEndelig avstengningstrykk
[MPa]Endelig strømningstrykk
[MPa]Bunnhullstrykk
[MPa]Borehullstemperatur
[°C]1.02.036.00026.00026.000Borestrengtester (DST) Test nummerOlje produksjon
[Sm3/dag]Gass produksjon
[Sm3/dag]Oljetetthet
[g/cm3]Gasstyngde rel. luftGOR
[m3/m3]1.01720447200.840262.01001394000.84039 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]CDL CNL GR18592762CDL GR4501875DIFL LS BHC GR4503524DIP18592759DLL MLL GR24502762FMT25622743FMT27973426MWD4493522SP24502762VSP10003920 -
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 formasjonstestCONDUCTOR30450.036455.00.00LOTSURF.COND.20969.026995.01.50LOTINTERM.13 3/81862.017 1/21878.01.90LOTINTERM.9 5/82750.012 1/42765.01.85LOTOPEN HOLE3526.08 1/23526.00.00LOT -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling4551.03WATER BASED23.09.19858551.6823.010.1WATER BASED16.12.19858961.118.043.0WATER BASED23.09.19859951.116.046.0WATER BASED23.09.198510001.1052.019.0WATER BASED26.09.198514481.2552.020.0WATER BASED30.09.198518581.4250.021.0WATER BASED30.09.198518781.4250.020.0WATER BASED30.09.198518781.4548.019.0WATER BASED01.10.198518781.5317.010.1WATER BASED07.10.198518781.4518.019.0WATER BASED02.10.198520221.5322.08.2WATER BASED07.10.198523451.6826.08.7WATER BASED07.10.198524751.6830.09.6WATER BASED07.10.198525601.6820.07.7WATER BASED18.11.198525601.6823.06.3WATER BASED18.11.198525611.6823.09.6WATER BASED18.11.198525611.6823.09.6WATER BASED20.11.198525611.6821.09.1WATER BASED25.11.198525611.6825.010.6WATER BASED25.11.198525621.6821.07.2WATER BASED07.10.198525621.6823.06.8WATER BASED07.10.198525621.6824.08.2WATER BASED07.10.198525641.6020.05.8WATER BASED21.10.198525641.6824.05.8WATER BASED21.10.198526111.6824.06.3WATER BASED08.10.198526121.6823.010.1WATER BASED09.12.198526201.6824.06.3WATER BASED11.10.198526401.6822.06.8WATER BASED11.10.198526861.6825.07.2WATER BASED03.11.198526861.6823.011.1WATER BASED19.11.198526861.6820.09.1WATER BASED28.11.198526861.6819.07.7WATER BASED01.12.198526861.6823.010.1WATER BASED09.12.198526861.6822.09.6WATER BASED09.12.198526861.6822.09.6WATER BASED16.12.198526861.6820.07.7WATER BASED18.11.198526861.6823.010.6WATER BASED19.11.198526861.6820.08.7WATER BASED27.11.198526861.6818.07.2WATER BASED28.11.198526861.6818.07.7WATER BASED28.11.198526861.6821.08.2WATER BASED01.12.198526861.6819.07.2WATER BASED01.12.198526861.6820.07.7WATER BASED01.12.198526861.6821.08.7WATER BASED04.12.198526861.6818.09.6WATER BASED09.12.198526861.6825.07.7WATER BASED04.11.198526861.6825.07.7WATER BASED05.11.198526861.6826.08.7WATER BASED08.11.198526861.6826.08.7WATER BASED11.11.198526861.6825.08.2WATER BASED11.11.198526861.6823.07.7WATER BASED13.11.198526861.6824.07.7WATER BASED13.11.198526861.6820.08.2WATER BASED18.11.198527501.6020.04.8WATER BASED31.10.198527501.6018.05.8WATER BASED21.10.198527651.6824.05.8WATER BASED16.10.198527651.6824.05.8WATER BASED16.10.198529051.6019.05.8WATER BASED24.10.198529321.6015.05.3WATER BASED24.10.198529601.6016.05.8WATER BASED24.10.198529881.6017.06.8WATER BASED24.10.198531331.6016.05.3WATER BASED24.10.198532801.6017.06.8WATER BASED28.10.198533361.6017.06.3WATER BASED28.10.198533381.6016.05.8WATER BASED28.10.198535261.6017.05.3WATER BASED31.10.198535261.6020.05.3WATER BASED31.10.198535261.6019.05.3WATER BASED31.10.1985 -
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