25/5-1
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Generell informasjon
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Brønnhistorie
GeneralWell 25/5-1 was drilled on a Jurassic structure straddling the two blocks 25/5 and 25/2. It is located near the crest of a westward tilted Jurassic fault block in the northern part of block 25/5. The northern extension of this structure was drilled in 1977 by well 25/2-6 which is located In the southern part of the neighbouring block 25/2, in a down dip position relative to well 25/5-1. Well 25/2-6 was plugged and abandoned with limited oil shows in sandstones of the Early Jurassic Statfjord Formation. The main objectives of well 25/5-1 were to test the hydrocarbon potential of the middle Jurassic Vestland Group sandstones and the Early Jurassic Statfjord Formation sandstones up dip of well 25/2-6.Operations and resultsWildcat well 25/5-1 was spudded 12 May 1987 by Norcem semi-submersible rig Nortrym and completed 1 August 1987 at a depth of 3430 m in the Triassic Group. Drilling proceeded without significant problems. There was no sign of shallow gas. One core was cut in the Draupne Formation between 2916 and 2925 m. Top reservoir (Hugin Formation) was encountered at 2984 m. Five cores were cut between 2990 - 3081 m in the Hugin and Sleipner formations and into the Drake Formation. The logs showed that the whole reservoir section contained oil down to base Sleipner / top Drake Formation, which formed a lithological sand / shale contact at 3060 m. RFT pressure measurements indicated an oil/water contact at ca 65 m below this level, implying a vertical oil column of 166 m. Due to this the hole was decided to be sidetracked to find the oil/water contact in the Sleipner Formation. Top Statfjord came in at 3232 m, and 3 cores were cut in the interval 3235 - 3291 m. There were shows down to 3264 m; below this depth the sandstones were water bearing. The Triassic was also water bearing. RFT fluid samples were taken at 3025 m and 2989.5 m. Both samples contained oil and mud filtrate.The well was plugged and abandoned on 1 August 1987 as an oil discovery.TestingThree DSTs were performed, two of them with re-runs due to technical problems.Three DSTs were performed, two of them with re-runs due to technical problems.DST 1 tested the interval 3233 to 3254 m in the Statfjord Group. This test did not produce formation flow to surface, but a bottom hole sample was taken, containing mud filtrate and water.DST 2A and 2B tested the interval 3025 to 3045 m in the Middle Sleipner Formation. DST 2A did not obtain reliable data due to technical problems. Bottom hole samples were taken. The re-run DST 2B produced 437 Sm3 oil/day through a 32/64 choke. The GOR was 201 m3/m3 and the oil density was 0.8373 g/cm3.DST 3A and 3B tested the interval 2987 to 3002 m in the Upper Sleipner Formation. DST 3A had technical problems and only the clean-up flow and the first build-up gave valid data. Maximum temperature measured at 2986.4 m was 106.4 C. The re-run DST 3B produced 442 Sm3/oil/day through a 32/64 choke. The GOR was 186 Sm3/Sm3 and the oil density was 0.825 g/cm3. -
Borekaks i Sokkeldirektoratet
Borekaks i Sokkeldirektoratet Borekaks tilgjengelig for prøvetaking?YESBorekaks i Sokkeldirektoratet Borekaksprøve, topp dybde [m]Borekaksprøve, bunn dybde [m]620.003430.00 -
Borekjerner i Sokkeldirektoratet
Borekjerner i Sokkeldirektoratet Kjerneprøve nummerKjerneprøve - topp dybdeKjerneprøve - bunn dybdeKjerneprøve dybde - enhet22990.03007.8[m ]33008.53027.3[m ]43027.53046.2[m ]53046.23063.5[m ]63064.03080.4[m ]73235.13253.0[m ]83253.53272.0[m ]93272.63291.0[m ]Borekjerner i Sokkeldirektoratet Total kjerneprøve lengde [m]143.9Borekjerner i Sokkeldirektoratet Kjerner tilgjengelig for prøvetaking?YES -
Kjernebilder
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Oljeprøver i Sokkeldirektoratet
Oljeprøver i Sokkeldirektoratet Test typeFlaske nummerTopp dyp
MD [m]Bunn dyp
MD [m]Væske typeTest tidspunktPrøver tilgjengeligDST0.000.00YESDSTDST33002.002987.00YESDSTDST3B3254.003233.0031.07.1987 - 00:00YES -
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 formasjonstestCONDUCTOR30203.036612.00.00LOTSURF.COND.20600.026815.01.14LOTINTERM.13 3/81978.017 1/22218.01.66LOTINTERM.9 5/82910.512 1/42941.01.86LOTLINER73429.08 1/23429.00.00LOT -
Borestrengtester (DST)
Borestrengtester (DST) Test nummerFra dybde MD
[m]Til dybde MD
[m]Reduksjonsventil størrelse
[mm]1.03233325412.72.03045302512.72.13045302512.73.03002298712.73.12987300212.7Borestrengtester (DST) Test nummerEndelig avstengningstrykk
[MPa]Endelig strømningstrykk
[MPa]Bunnhullstrykk
[MPa]Borehullstemperatur
[°C]1.02.08.0002.130.00011.00030.0003.010.0003.132.000Borestrengtester (DST) Test nummerOlje produksjon
[Sm3/dag]Gass produksjon
[Sm3/dag]Oljetetthet
[g/cm3]Gasstyngde rel. luftGOR
[m3/m3]1.02.0396710000.8270.7051782.1437880000.8370.7052013.0339740000.8250.7902173.1442820000.8250.815186 -
Logger
Logger Type loggTopp dyp for logg [m]Bunn dyp for logg [m]BGT5981972CBL VDL3102910CST GR20863410DIL LSS GR5983427DLL MSFL GR29103425LDT CNL EPT NGT29103429LDT CNL GR29103149LDT GR5982916MWD2193426RFT GR02989RFT GR29853058RFT GR32343399SHDT GR19773429VSP11003425 -
Litostratigrafi
Litostratigrafi Topp Dyb [mMD RKB]Litostrat. enhet14344492095111021287134521692169220022142240227524002570258825882802290029052905295529842984299630603060312932323374 -
Spleisede logger
Spleisede logger Dokument navnDokument formatDokument størrelse [KB]pdf0.51 -
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk)
Dokumenter – rapportert av utvinningstillatelsen (frigitt ihht til regelverk) Dokument navnDokument formatDokument størrelse [KB]pdf26.28 -
Dokumenter – eldre Sokkeldirektoratets WDSS rapporter og andre relaterte dokumenter
Dokumenter – eldre Sokkeldirektoratets WDSS rapporter og andre relaterte dokumenter Dokument navnDokument formatDokument størrelse [KB]pdf0.44pdf0.27 -
Boreslam
Boreslam Dybde MD [m]Egenvekt, slam [g/cm3]Viskositet, slam [mPa.s]Flytegrense [Pa]Type slamDato, måling11871.0930.07.8WATER BASED21.05.198713581.1028.05.8WATER BASED21.05.198718571.1332.08.8WATER BASED25.05.198719961.1524.06.8WATER BASED25.05.198722181.1318.04.9WATER BASED29.05.198722391.1319.04.9WATER BASED02.06.198724971.1418.04.4WATER BASED02.06.198725811.14182.05.8WATER BASED02.06.198726411.1419.04.9WATER BASED03.06.198727291.1419.05.8WATER BASED04.06.198727461.1419.04.9WATER BASED09.06.198728831.1423.06.8WATER BASED09.06.198729161.1426.06.8WATER BASED09.06.198729251.1526.06.8WATER BASED09.06.198729411.2128.05.3WATER BASED15.06.198729671.2235.07.3WATER BASED16.06.198729941.2234.05.3WATER BASED16.06.198730791.2231.05.8WATER BASED22.06.198731421.2228.05.8WATER BASED22.06.198731471.2228.05.8WATER BASED22.06.198731621.2226.05.8WATER BASED22.06.198732351.2427.05.8WATER BASED23.06.198732541.2431.05.8WATER BASED24.06.198732911.2431.05.8WATER BASED25.06.198733331.2429.05.8WATER BASED26.06.198734301.2432.05.8WATER BASED29.06.1987 -
Palynologiske preparater i Sokkeldirektoratet
Palynologiske preparater i Sokkeldirektoratet Prøve dybdeDybde enhetPrøve typeLaboratorie2922.4[m]CAPT2923.8[m]CAPT2950.0[m]DC2972.0[m]DC2980.0[m]DC2982.0[m]DC2983.0[m]DC2987.0[m]DC2990.3[m]C2990.3[m]COD2990.8[m]CAPT2991.4[m]CAPT2992.3[m]C2992.3[m]CAPT2992.3[m]COD2992.8[m]CAPT2992.8[m]COD2993.7[m]COD2994.2[m]CAPT2994.5[m]CAPT2994.5[m]COD2994.5[m]C2994.8[m]CAPT2995.0[m]DC2996.0[m]COD2996.3[m]C2996.9[m]CAPT2997.3[m]C2998.2[m]COD2998.3[m]C2998.7[m]CAPT2998.8[m]CAPT2998.9[m]CAPT2999.0[m]COD2999.3[m]C3000.0[m]CAPT3000.5[m]C3000.5[m]COD3001.7[m]CAPT3002.5[m]C3003.5[m]COD3004.5[m]C3004.8[m]CAPT3005.0[m]CAPT3005.5[m]C3005.5[m]CAPT3006.5[m]COD3006.5[m]C3006.6[m]CAPT3007.8[m]CAPT3008.5[m]CAPT3008.7[m]COD3008.8[m]CAPT3008.8[m]C3009.1[m]CAPT3009.2[m]CAPT3009.7[m]COD3009.8[m]C3010.5[m]C3011.5[m]C3012.3[m]COD3013.5[m]C3015.4[m]C3016.4[m]COD3016.5[m]COD3017.5[m]C3019.5[m]C3020.4[m]COD3021.5[m]C3023.5[m]C3025.5[m]C3025.7[m]COD3027.0[m]C3028.5[m]C3030.5[m]C3031.5[m]COD3032.5[m]C3034.7[m]COD3034.8[m]C3034.8[m]CAPT3035.5[m]C3037.5[m]C3038.2[m]CAPT3038.4[m]CAPT3038.5[m]COD3039.5[m]C3040.5[m]CAPT3041.5[m]C3042.3[m]CAPT3042.8[m]CAPT3042.8[m]COD3043.1[m]COD3043.3[m]CAPT3044.0[m]C3044.7[m]CAPT3044.8[m]C3044.8[m]CAPT3045.4[m]CAPT3045.5[m]COD3046.5[m]CAPT3046.5[m]CAPT3046.7[m]CAPT3046.9[m]CAPT3047.8[m]C3048.2[m]CAPT3048.8[m]CAPT3048.8[m]COD3049.0[m]C3049.2[m]CAPT3049.5[m]CAPT3050.4[m]CAPT3051.0[m]C3051.8[m]CAPT3052.0[m]CAPT3052.0[m]COD3052.4[m]CAPT3052.7[m]CAPT3053.2[m]CAPT3053.8[m]C3054.0[m]COD3054.2[m]CAPT3054.4[m]CAPT3054.6[m]CAPT3055.0[m]C3055.3[m]CAPT3055.3[m]COD3055.9[m]CAPT3056.5[m]C3056.6[m]CAPT3057.5[m]CAPT3057.6[m]COD3058.7[m]CAPT3060.9[m]CAPT3061.0[m]C3078.0[m]C3094.0[m]C3125.5[m]C3131.0[m]C3142.0[m]C3155.5[m]C3171.0[m]C3190.0[m]C3212.0[m]C3220.5[m]C3235.8[m]C3236.8[m]C3238.3[m]C3240.0[m]C3240.3[m]C3241.3[m]C3242.8[m]C3244.0[m]C3244.5[m]C3245.8[m]C3247.0[m]C3248.3[m]C3249.8[m]C3251.3[m]C3254.0[m]C3255.5[m]C3256.0[m]C3257.3[m]C3258.5[m]C3259.0[m]C3261.0[m]C3263.0[m]C3264.5[m]C3266.0[m]C3268.0[m]C3280.0[m]C3285.5[m]C3289.0[m]C3334.5[m]C3340.0[m]C3349.0[m]C3362.0[m]C3376.0[m]C3383.0[m]C3386.7[m]C3392.5[m]C3399.0[m]C3408.0[m]C