34/7-5
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Generell informasjon
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Brønnhistorie
GeneralWell 34/7-5 is located in the Statfjord Øst area of the Northern North Sea. The primary objectives of the well were to test the reservoir potential of the Brent Group, and to determine if the oil/water contact is the same as that found in the 33/9-7 Statfjord Øst discovery well drilled to the south southwest of this well in the neighbouring block, but on the assumed same structure. A secondary objective was to test the reservoir potential of the Statfjord Formation.Operations and resultsWildcat well 34/7-5 was spudded with the semi-submersible installation Treasure Saga on 17 January 1985 and drilled to TD at 3146 m in the Late Triassic Lunde Formation. Drilling proceeded without significant problems. The well was drilled with spud mud down to 930 m and with gypsum/polymer mud from 930 m to TD.Trace oil shows appeared in sandstone lamina in the Cretaceous from about 2380, limestones had shows from about 2488 m. The Brent Group reservoir came in at 2502 m, approximately 60 m deeper than prognosed. Hydrocarbons were encountered in the upper section belonging to the Ness Formation. The oil/water contact could not be defined from pressure data. From shows on cores and the well logs an OWC could be placed at approximately 2521 m, in accordance with the results from well 33/9-7. Below the OWC oil shows on sandstone decreased gradually from 2523 m until they vanished at 2616 m. The Statfjord Formation was dry.Eleven cores were cut. Cores 1 to 10 were cut from 2508 m to 2633 m in the Brent Group and the uppermost part of the Drake Formation. Core 1, from 2508 to 2510 gave no recovery. The core depths for Cores 2 to 10 were from 0.5 m to 2.2 m short of logger's depth. Core 11 was cut from 2869 m to 2883.5 m in the calcareous Amundsen Formation. For this core there was no difference between core depth and logger's depth. No wire line fluid samples were taken.The well was permanently abandoned on 16 March 1985 as an oil appraisal.TestingTwo drill stem tests were performed from the interval 2502.5 - 2512.5 m.The first test, DST 1, produced oil with a water cut of 50%, strongly suggesting water channelling behind casing from the underlying water zone.Cement was squeezed behind casing to isolate the perforated zone and a second repeat test, DST 1A was initiated. This test produced clean oil at a rate of 260 Sm3 /day through a 9.5 mm choke. The wellhead pressure was 72 bar. The highest recorded bottom hole temperature was 88 deg C in both DST 1 and in DST 1A. -
Borekaks i Sokkeldirektoratet
Borekaks i Sokkeldirektoratet Borekaks tilgjengelig for prøvetaking?YESBorekaks i Sokkeldirektoratet Borekaksprøve, topp dybde [m]Borekaksprøve, bunn dybde [m]390.003147.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet22510.02520.7[m ]32521.02527.3[m ]42529.52541.2[m ]52542.02555.1[m ]62555.12571.9[m ]72573.02590.7[m ]82591.02607.5[m ]92609.02622.2[m ]102624.02631.6[m ]112869.02883.4[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]127.7Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Kjernebilder
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Palynologiske preparater i Sokkeldirektoratet
Palynologiske preparater i Sokkeldirektoratet Prøve dybdeDybde enhetPrøve typeLaboratorie2148.0[m]DCRRI2166.0[m]DCRRI2196.0[m]DCRRI2211.0[m]DCRRI2241.0[m]DCRRI2256.0[m]DCRRI2271.0[m]DCRRI2320.0[m]DCRRI2510.5[m]CRRI2535.0[m]DCRRI2556.0[m]DCRRI2565.0[m]DCRRI2577.0[m]DCRRI2598.0[m]DCRRI2610.0[m]DCRRI2621.4[m]CRRI2624.3[m]CRRI2626.0[m]CRRI2628.7[m]CRRI2631.3[m]CRRI2709.0[m]DCRRI2727.0[m]DCRRI2739.0[m]DCRRI2781.0[m]DCRRI2796.0[m]DCRRI2811.0[m]DCRRI2826.0[m]DCRRI2895.0[m]DCRRI2910.0[m]DCRRI -
Oljeprøver i Sokkeldirektoratet
Oljeprøver i Sokkeldirektoratet Test typeFlaske nummerTopp dyp
MD [m]Bunn dyp
MD [m]Væske typeTest tidspunktPrøver tilgjengeligDSTDST1A2502.502512.5008.03.1985 - 01:00YES -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet270107510821094123913301670167017381841188519111911209024852485248924962496250225022531256426222622269627682794289330103010 -
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]pdf0.30pdf0.28 -
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk)
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk) Dokument navnDokument formatDokumentstørrelse [MB]pdf1.94pdf41.54 -
Borestrengtester (DST)
Borestrengtester (DST) Test nummerFra dybde MD
[m]Til dybde MD
[m]Reduksjonsventil størrelse
[mm]1.0250325129.52.0250225129.5Borestrengtester (DST) Test nummerEndelig avstengningstrykk
[MPa]Endelig strømningstrykk
[MPa]Bunnhullstrykk
[MPa]Borehullstemperatur
[°C]1.013.0009.00036.0002.011.000Borestrengtester (DST) Test nummerOlje produksjon
[Sm3/dag]Gass produksjon
[Sm3/dag]Oljetetthet
[g/cm3]Gasstyngde rel. luftGOR
[m3/m3]1.0318460000.0850.7601452.026240000.845151 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]ACBL6801840CDL CNL GR18432746CDL CNL GR24703143CDL GR379929CDL GR9121860DIFL LSBHC GR379929DIFL LSBHC GR9121863DIFL LSBHC GR18403143DIPLOG18403143DLL MLL GR24502746FMT18403143FMT18432746GR120384SIGNATURE24402610SIGNATURE28913115SWC00VSP3803131 -
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 formasjonstestCONDUCTOR30380.036790.00.00LOTSURF.COND.20913.026930.01.52LOTINTERM.13 3/81844.017 1/21865.01.79LOTINTERM.9 5/82636.012 1/43146.00.00LOT -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling3841.03WATER BASED18.01.19857901.10WATER BASED25.01.19859301.12WATER BASED25.01.198511641.1010.017.0WATER BASED29.01.198514891.2210.013.0WATER BASED29.01.198517851.4020.022.0WATER BASED29.01.198518651.4319.018.0WATER BASED29.01.198518651.4350.018.0WATER BASED29.01.198518651.4350.018.0WATER BASED29.01.198519851.5255.018.0WATER BASED31.01.198521381.6255.016.0WATER BASED01.02.198523251.6655.020.0WATER BASED04.02.198524341.6950.015.0WATER BASED04.02.198524541.6952.015.0WATER BASED04.02.198526721.6855.016.0WATER BASED12.02.198527501.6864.017.0WATER BASED13.02.198527501.6854.013.0WATER BASED14.02.198527501.6854.013.0WATER BASED14.02.198527941.6351.018.0WATER BASED15.02.198528361.6451.018.0WATER BASED18.02.1985 -
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