Generell informasjon Brønnbane navn Type Formål Status Faktakart i nytt vindu Hovedområde Felt Funn 2/11-3 A EXPLORATION APPRAISAL P&A lenke NORTH SEA HOD 2/11-10 S Brønn navn 2/11-3 Seismisk lokalisering Boret i utvinningstillatelse 033 Boreoperatør Boretillatelse 192-L Boreinnretning Bore dager 101 Amoco Norway Oil Company DYVI BETA Borestart 03.12.1977 Boreslutt 13.03.1978 Frigitt dato 13.03.1980 Publiseringsdato 22.03.2013 Opprinnelig formål Gjenåpnet Innhold Funnbrønnbane APPRAISAL NO OIL NO 1. nivå med hydrokarboner, alder PALEOCENE 1. nivå med hydrokarboner, formasjon EKOFISK FM 2. nivå med hydrokarboner, alder LATE CRETACEOUS 2. nivå med hydrokarboner, formasjon TOR FM 3. nivå med hydrokarboner, alder LATE CRETACEOUS 3. nivå med hydrokarboner, formasjon Avstand, boredekk - midlere havflate Vanndybde ved midlere havflate HOD FM 36.0 72.0 Totalt målt dybde (MD) [m RKB] 3400.0 Totalt vertikalt dybde (TVD) [m RKB] 2857.0 Maks inklinasjon [ ] 53.4 Side 1 av 6
Temperatur ved bunn av brønnbanen [ C] Eldste penetrerte alder Eldste penetrerte formasjon Geodetisk datum NS grader ØV grader 110 LATE CRETACEOUS HOD FM ED50 56 10' 53.74'' N 3 27' 51.78'' E NS UTM 6226525.75 ØV UTM 528827.92 UTM sone 31 NPDID for brønnbanen 287 Brønnhistorie Side 2 av 6
General The Hod complex was proved to consist of two individual structures by well 2/11-3, which was drilled about 2.5 km due east of 2/11-2. Seismically, the Hod structural complex is difficult to map due to shallow gas in the Tertiary, mainly over the western part of the structure, which complicates the time to depth conversion. As it turned out, the chalk in 2/11-2 was drilled close to the limit of structural closure of the East Structure and was therefore dry with shows only. Well 2/11-3 A was a sidetrack from well 2/11-3 to test Late Cretaceous chalk in a graben feature indicated by seismic in the crestal regional of the East Hod structure. A graben, if present, would have possibilities for preservation of younger Maastrichtian rock which in general is of high reservoir quality with high porosity and often very high oil saturation. Operations and results Well 2/11-3A was sidetracked from just below the 13 3/8-inch casing shoe on 3 December 197 7 and drilled to TD at a total measured depth of 3400 m (2857 m TVD) in the Late Cretaceous Hod Formation. The pipe stuck at TD prior to logging and deviation survey. After working on the stuck pipe the string was disconnected at 3189 m and the well was kicked-off on the low side in order to complete logging and testing of the payzone discovered before the pipe got stuck. This technical sidetrack was drilled to 3333 m (2812 m TVD). Top Chalk was encountered in the sidetrack at 3189.5 meters (2713 meters TVD). The uppermost 5 m belonged to the Ekofisk Formation. Then followed 58.5 m of Tor Formation, 13 m of tight Middle Hod Formation, and 70 m of Lower Hod. The Chalk was found oil bearing from top Chalk to TD in the sidetrack, with exception of 8 m in Middle Hod. Shows on cuttings were recorded in the primary well bore down to 3370 m. No oil shows were reported from above top Chalk. Seven cores were cut in the top Chalk section in the primary un-logged well bore in the interval from 3192.4 m to 3250.3 m. Recovery varied from 18 % to 100 %. No wire line fluid samples were taken. The well was permanently abandoned on 13 March 1978 as an oil appraisal well. Testing Two Drill Stem Tests were conducted in the well. DST 1 tested the interval 3268 to 3280 m. After hydraulic fracturing the test flowed on average 88 Sm3 oil and 12700 Sm3 gas /day through a 24/64" choke. The average GOR was 133 Sm3/Sm3, the oil gravity was 29.1 deg API, and the gas gravity was 0.8 (air=1). Maximum temperature recorded down hole was 102 deg C. A final flow on a 32/64" choke gave sluggish flow but did not increase rates much. DST 2 tested the interval 3230 to 3236 m. After acid stimulation the test flowed on average 915 Sm3 oil and 104500 Sm3 gas /day through a 32/64" choke. The average GOR was 114 Sm3/Sm3, the oil gravity was 33.9 deg API and the gas gravity was 0.69 (air = 1). Maximum temperature recorded down hole was 107 deg C. Borekaks i OD Borekaksprøve, topp dybde Borekaksprøve, bunn dybde 1298.46 3162.50 Side 3 av 6
Borekaksprøve tilgjengelig YES Borekjerner i OD Kjerneprøve Kjerneprøve - topp dybde Kjerneprøve - bunn Kjerneprøve dybde dybde - enhet 1 3192.0 3198.3 [m ] 2 3201.5 3206.3 [m ] 3 3206.3 3209.9 [m ] 4 3226.0 3230.1 [m ] 5 3231.9 3235.7 [m ] 6 3235.9 3239.1 [m ] 7 3240.9 3251.4 [m ] Total kjerneprøve lengde 36.3 Kjerneprøve tilgjengelig YES Kjernebilder 3192-3194m 3194-3197m 3197-3198m 3201-3204m 3204-3206m 3206-3209m 3209-3209m 3226-3228m 3228-3230m 3231-3234m 3234-3235m 3235-3238m 3238-3239m 3240-3243m 3243-3245m Side 4 av 6
3245-3248m 3248-3250m 3250-3252m er - eldre OD WDSS rapporter og andre relaterte dokumenter navn format størrelse [KB] 287_01_WDSS_General_Information pdf 0.25 287_03_WDSS_lithlog pdf 0.05 er - rapportert av utvinningstillatelsen (frigitt ihht til regelverk) navn format størrelse [KB] 287_2_11_3_A_Completionlog pdf 1.75 Borestrengtester (DST) Test Fra dybde MD Til dybde MD Reduksjonsven til størrelse [mm] 1.0 3268 3280 9.5 2.0 3230 3236 9.5 Test Endelig avstengningstrykk [MPa] Endelig strømningstrykk [MPa] Bunnhullstrykk [MPa] Borehullstempera tur [ C] 1.0 2.0 Test Olje produksjon [Sm3/dag] Gass produksjon [Sm3/dag] Oljetetthet [g/cm3] Gasstyngde rel. luft 1.0 88 12743 0.880 0.800 2.0 519 63429 0.840 0.690 GOR [m3/m3 ] Side 5 av 6
Logger Type logg Topp dyp Bunn dyp for for logg logg CBL VDL TT 849 3114 CBL VDL TT GR 2996 3298 CBL VDL TT GR 3000 3287 CNL FDC GR CAL 3121 3335 CONT-DIP 3126 3327 DLL MSFL GR SP CAL 3127 3334 ISF SON SP GR 1280 2055 TEMP 150 2838 TEMP 3100 3272 Foringinsrør og formasjonsstyrketester Type utforing Utforing diam. [tommer] Utforing dybde Brønnbane diam. [tommer] Brønnbane dyp Slam egenvekt ekvivalent [g/cm3] Type formasjonstest INTERM. 9 5/8 3129.0 12 1/4 3130.0 1.88 LOT OPEN HOLE 3400.0 8 1/2 3400.0 0.00 LOT Boreslam Dybde Egenvekt, Viskositet, Flytegrense Type slam MD slam [g/cm3] slam [mpa.s] [Pa] 2446 1.79 waterbased 3288 1.74 waterbased Dato, måling Side 6 av 6