Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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25/5-1

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    25/5-1
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    WILDCAT
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    25/5-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    EL 8503 - 417 SP. 600
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    Elf Petroleum Norge AS
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    543-L
    Drilling facility
    Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.
    Drilling days
    Number of days from wellbore entry to wellbore completion.
    82
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    12.05.1987
    Completed date
    Exploration wellbores from moveable facilities:
    For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores:
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    01.08.1987
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    01.08.1989
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    17.12.2003
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    OIL
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    YES
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    MIDDLE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    HUGIN FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    SLEIPNER FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    118.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3429.0
    Final vertical depth (TVD) [m RKB]
    Vertical elevation from total depth to kelly bushing. Shown only for released wells. Referred to as true vertical depth (TVD).
    3429.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    122
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    TRIASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    NO GROUP DEFINED
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 43' 47.19'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 34' 13.46'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6621549.92
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    475841.98
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    884

  • Wellbore history
    General
    Well 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 results
    Wildcat 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.
    Testing
    Three 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.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    620.00
    3430.00

  • Cores at the Norwegian Offshore Directorate
    Cores at the Norwegian Offshore Directorate
    Core sample number
    Core sample - top depth
    Core sample - bottom depth
    Core sample depth - uom
    2
    2990.0
    3007.8
    [m ]
    3
    3008.5
    3027.3
    [m ]
    4
    3027.5
    3046.2
    [m ]
    5
    3046.2
    3063.5
    [m ]
    6
    3064.0
    3080.4
    [m ]
    7
    3235.1
    3253.0
    [m ]
    8
    3253.5
    3272.0
    [m ]
    9
    3272.6
    3291.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    143.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2990-2995m
    Core photo at depth: 2995-3000m
    Core photo at depth: 3000-3005m
    Core photo at depth: 3005-3007m
    Core photo at depth: 3008-3013m
    2990-2995m
    2995-3000m
    3000-3005m
    3005-3007m
    3008-3013m
    Core photo at depth: 3013-3018m
    Core photo at depth: 3018-3023m
    Core photo at depth: 3023-3027m
    Core photo at depth: 3027-3032m
    Core photo at depth: 3032-3037m
    3013-3018m
    3018-3023m
    3023-3027m
    3027-3032m
    3032-3037m
    Core photo at depth: 3037-3042m
    Core photo at depth: 3042-3048m
    Core photo at depth: 3046-3051m
    Core photo at depth: 3051-3056m
    Core photo at depth: 3056-3061m
    3037-3042m
    3042-3048m
    3046-3051m
    3051-3056m
    3056-3061m
    Core photo at depth: 3061-3063m
    Core photo at depth: 3064-3069m
    Core photo at depth: 3069-3074m
    Core photo at depth: 3074-3079m
    Core photo at depth: 3079-3080m
    3061-3063m
    3064-3069m
    3069-3074m
    3074-3079m
    3079-3080m
    Core photo at depth: 3235-3240m
    Core photo at depth: 3240-3245m
    Core photo at depth: 3245-3250m
    Core photo at depth: 3250-3253m
    Core photo at depth: 3253-3258m
    3235-3240m
    3240-3245m
    3245-3250m
    3250-3253m
    3253-3258m
    Core photo at depth: 3258-3263m
    Core photo at depth: 3263-3268m
    Core photo at depth: 3268-3272m
    Core photo at depth: 3272-3277m
    Core photo at depth: 3277-3282m
    3258-3263m
    3263-3268m
    3268-3272m
    3272-3277m
    3277-3282m
    Core photo at depth: 3282-3287m
    Core photo at depth: 3287-3291m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3282-3287m
    3287-3291m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2922.4
    [m]
    C
    APT
    2923.8
    [m]
    C
    APT
    2950.0
    [m]
    DC
    2972.0
    [m]
    DC
    2980.0
    [m]
    DC
    2982.0
    [m]
    DC
    2983.0
    [m]
    DC
    2987.0
    [m]
    DC
    2990.3
    [m]
    C
    2990.3
    [m]
    C
    OD
    2990.8
    [m]
    C
    APT
    2991.4
    [m]
    C
    APT
    2992.3
    [m]
    C
    2992.3
    [m]
    C
    APT
    2992.3
    [m]
    C
    OD
    2992.8
    [m]
    C
    APT
    2992.8
    [m]
    C
    OD
    2993.7
    [m]
    C
    OD
    2994.2
    [m]
    C
    APT
    2994.5
    [m]
    C
    APT
    2994.5
    [m]
    C
    OD
    2994.5
    [m]
    C
    2994.8
    [m]
    C
    APT
    2995.0
    [m]
    DC
    2996.0
    [m]
    C
    OD
    2996.3
    [m]
    C
    2996.9
    [m]
    C
    APT
    2997.3
    [m]
    C
    2998.2
    [m]
    C
    OD
    2998.3
    [m]
    C
    2998.7
    [m]
    C
    APT
    2998.8
    [m]
    C
    APT
    2998.9
    [m]
    C
    APT
    2999.0
    [m]
    C
    OD
    2999.3
    [m]
    C
    3000.0
    [m]
    C
    APT
    3000.5
    [m]
    C
    3000.5
    [m]
    C
    OD
    3001.7
    [m]
    C
    APT
    3002.5
    [m]
    C
    3003.5
    [m]
    C
    OD
    3004.5
    [m]
    C
    3004.8
    [m]
    C
    APT
    3005.0
    [m]
    C
    APT
    3005.5
    [m]
    C
    3005.5
    [m]
    C
    APT
    3006.5
    [m]
    C
    OD
    3006.5
    [m]
    C
    3006.6
    [m]
    C
    APT
    3007.8
    [m]
    C
    APT
    3008.5
    [m]
    C
    APT
    3008.7
    [m]
    C
    OD
    3008.8
    [m]
    C
    APT
    3008.8
    [m]
    C
    3009.1
    [m]
    C
    APT
    3009.2
    [m]
    C
    APT
    3009.7
    [m]
    C
    OD
    3009.8
    [m]
    C
    3010.5
    [m]
    C
    3011.5
    [m]
    C
    3012.3
    [m]
    C
    OD
    3013.5
    [m]
    C
    3015.4
    [m]
    C
    3016.4
    [m]
    C
    OD
    3016.5
    [m]
    C
    OD
    3017.5
    [m]
    C
    3019.5
    [m]
    C
    3020.4
    [m]
    C
    OD
    3021.5
    [m]
    C
    3023.5
    [m]
    C
    3025.5
    [m]
    C
    3025.7
    [m]
    C
    OD
    3027.0
    [m]
    C
    3028.5
    [m]
    C
    3030.5
    [m]
    C
    3031.5
    [m]
    C
    OD
    3032.5
    [m]
    C
    3034.7
    [m]
    C
    OD
    3034.8
    [m]
    C
    3034.8
    [m]
    C
    APT
    3035.5
    [m]
    C
    3037.5
    [m]
    C
    3038.2
    [m]
    C
    APT
    3038.4
    [m]
    C
    APT
    3038.5
    [m]
    C
    OD
    3039.5
    [m]
    C
    3040.5
    [m]
    C
    APT
    3041.5
    [m]
    C
    3042.3
    [m]
    C
    APT
    3042.8
    [m]
    C
    APT
    3042.8
    [m]
    C
    OD
    3043.1
    [m]
    C
    OD
    3043.3
    [m]
    C
    APT
    3044.0
    [m]
    C
    3044.7
    [m]
    C
    APT
    3044.8
    [m]
    C
    3044.8
    [m]
    C
    APT
    3045.4
    [m]
    C
    APT
    3045.5
    [m]
    C
    OD
    3046.5
    [m]
    C
    APT
    3046.5
    [m]
    C
    APT
    3046.7
    [m]
    C
    APT
    3046.9
    [m]
    C
    APT
    3047.8
    [m]
    C
    3048.2
    [m]
    C
    APT
    3048.8
    [m]
    C
    APT
    3048.8
    [m]
    C
    OD
    3049.0
    [m]
    C
    3049.2
    [m]
    C
    APT
    3049.5
    [m]
    C
    APT
    3050.4
    [m]
    C
    APT
    3051.0
    [m]
    C
    3051.8
    [m]
    C
    APT
    3052.0
    [m]
    C
    APT
    3052.0
    [m]
    C
    OD
    3052.4
    [m]
    C
    APT
    3052.7
    [m]
    C
    APT
    3053.2
    [m]
    C
    APT
    3053.8
    [m]
    C
    3054.0
    [m]
    C
    OD
    3054.2
    [m]
    C
    APT
    3054.4
    [m]
    C
    APT
    3054.6
    [m]
    C
    APT
    3055.0
    [m]
    C
    3055.3
    [m]
    C
    APT
    3055.3
    [m]
    C
    OD
    3055.9
    [m]
    C
    APT
    3056.5
    [m]
    C
    3056.6
    [m]
    C
    APT
    3057.5
    [m]
    C
    APT
    3057.6
    [m]
    C
    OD
    3058.7
    [m]
    C
    APT
    3060.9
    [m]
    C
    APT
    3061.0
    [m]
    C
    3078.0
    [m]
    C
    3094.0
    [m]
    C
    3125.5
    [m]
    C
    3131.0
    [m]
    C
    3142.0
    [m]
    C
    3155.5
    [m]
    C
    3171.0
    [m]
    C
    3190.0
    [m]
    C
    3212.0
    [m]
    C
    3220.5
    [m]
    C
    3235.8
    [m]
    C
    3236.8
    [m]
    C
    3238.3
    [m]
    C
    3240.0
    [m]
    C
    3240.3
    [m]
    C
    3241.3
    [m]
    C
    3242.8
    [m]
    C
    3244.0
    [m]
    C
    3244.5
    [m]
    C
    3245.8
    [m]
    C
    3247.0
    [m]
    C
    3248.3
    [m]
    C
    3249.8
    [m]
    C
    3251.3
    [m]
    C
    3254.0
    [m]
    C
    3255.5
    [m]
    C
    3256.0
    [m]
    C
    3257.3
    [m]
    C
    3258.5
    [m]
    C
    3259.0
    [m]
    C
    3261.0
    [m]
    C
    3263.0
    [m]
    C
    3264.5
    [m]
    C
    3266.0
    [m]
    C
    3268.0
    [m]
    C
    3280.0
    [m]
    C
    3285.5
    [m]
    C
    3289.0
    [m]
    C
    3334.5
    [m]
    C
    3340.0
    [m]
    C
    3349.0
    [m]
    C
    3362.0
    [m]
    C
    3376.0
    [m]
    C
    3383.0
    [m]
    C
    3386.7
    [m]
    C
    3392.5
    [m]
    C
    3399.0
    [m]
    C
    3408.0
    [m]
    C

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    0.00
    0.00
    YES
    DST
    DST3
    3002.00
    2987.00
    YES
    DST
    DST3B
    3254.00
    3233.00
    31.07.1987 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.51

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    pdf
    26.28

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3233
    3254
    12.7
    2.0
    3045
    3025
    12.7
    2.1
    3045
    3025
    12.7
    3.0
    3002
    2987
    12.7
    3.1
    2987
    3002
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    8.000
    2.1
    30.000
    11.000
    30.000
    3.0
    10.000
    3.1
    32.000
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    2.0
    396
    71000
    0.827
    0.705
    178
    2.1
    437
    88000
    0.837
    0.705
    201
    3.0
    339
    74000
    0.825
    0.790
    217
    3.1
    442
    82000
    0.825
    0.815
    186

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT
    598
    1972
    CBL VDL
    310
    2910
    CST GR
    2086
    3410
    DIL LSS GR
    598
    3427
    DLL MSFL GR
    2910
    3425
    LDT CNL EPT NGT
    2910
    3429
    LDT CNL GR
    2910
    3149
    LDT GR
    598
    2916
    MWD
    219
    3426
    RFT GR
    0
    2989
    RFT GR
    2985
    3058
    RFT GR
    3234
    3399
    SHDT GR
    1977
    3429
    VSP
    1100
    3425

  • Casing and leak–off tests
    Casing and leak–off tests
    Casing type
    Casing diam.
    [inch]
    Casing depth
    [m]
    Hole diam.
    [inch]
    Hole depth
    [m]
    LOT/FIT mud eqv.
    [g/cm3]
    Formation test type
    CONDUCTOR
    30
    203.0
    36
    612.0
    0.00
    LOT
    SURF.COND.
    20
    600.0
    26
    815.0
    1.14
    LOT
    INTERM.
    13 3/8
    1978.0
    17 1/2
    2218.0
    1.66
    LOT
    INTERM.
    9 5/8
    2910.5
    12 1/4
    2941.0
    1.86
    LOT
    LINER
    7
    3429.0
    8 1/2
    3429.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1187
    1.09
    30.0
    7.8
    WATER BASED
    21.05.1987
    1358
    1.10
    28.0
    5.8
    WATER BASED
    21.05.1987
    1857
    1.13
    32.0
    8.8
    WATER BASED
    25.05.1987
    1996
    1.15
    24.0
    6.8
    WATER BASED
    25.05.1987
    2218
    1.13
    18.0
    4.9
    WATER BASED
    29.05.1987
    2239
    1.13
    19.0
    4.9
    WATER BASED
    02.06.1987
    2497
    1.14
    18.0
    4.4
    WATER BASED
    02.06.1987
    2581
    1.14
    182.0
    5.8
    WATER BASED
    02.06.1987
    2641
    1.14
    19.0
    4.9
    WATER BASED
    03.06.1987
    2729
    1.14
    19.0
    5.8
    WATER BASED
    04.06.1987
    2746
    1.14
    19.0
    4.9
    WATER BASED
    09.06.1987
    2883
    1.14
    23.0
    6.8
    WATER BASED
    09.06.1987
    2916
    1.14
    26.0
    6.8
    WATER BASED
    09.06.1987
    2925
    1.15
    26.0
    6.8
    WATER BASED
    09.06.1987
    2941
    1.21
    28.0
    5.3
    WATER BASED
    15.06.1987
    2967
    1.22
    35.0
    7.3
    WATER BASED
    16.06.1987
    2994
    1.22
    34.0
    5.3
    WATER BASED
    16.06.1987
    3079
    1.22
    31.0
    5.8
    WATER BASED
    22.06.1987
    3142
    1.22
    28.0
    5.8
    WATER BASED
    22.06.1987
    3147
    1.22
    28.0
    5.8
    WATER BASED
    22.06.1987
    3162
    1.22
    26.0
    5.8
    WATER BASED
    22.06.1987
    3235
    1.24
    27.0
    5.8
    WATER BASED
    23.06.1987
    3254
    1.24
    31.0
    5.8
    WATER BASED
    24.06.1987
    3291
    1.24
    31.0
    5.8
    WATER BASED
    25.06.1987
    3333
    1.24
    29.0
    5.8
    WATER BASED
    26.06.1987
    3430
    1.24
    32.0
    5.8
    WATER BASED
    29.06.1987

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.22