Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.07.2024 - 01:27
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6506/12-8

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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.
    6506/12-8
    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).
    APPRAISAL
    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.
    NORWEGIAN 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.
    6506/12-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8701 - 529 SP 858
    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.
    Den norske stats oljeselskap a.s
    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.
    579-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.
    88
    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,
    04.06.1988
    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.
    30.08.1988
    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.
    30.08.1990
    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.
    28.06.2007
    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.
    APPRAISAL
    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/GAS
    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.
    NO
    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.
    FANGST GP
    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.
    EARLY 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.
    TILJE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    296.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4335.0
    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).
    4334.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    149
    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.
    EARLY JURASSIC
    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.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 0' 59.32'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 56' 58.75'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7212038.59
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    403380.37
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    1068
  • Wellbore history

    General
    Well 6506/12-8 is located in the Haltenbanken area off shore Mid Norway. It was designed to appraise the Smørbukk South discovery in the southern part of the block. The main objective was to establish productivity in the Garn Formation down flank of well 6506/12-3, the fluid properties, and to provide better understanding of diagenesis effects. In the Ile Formation the gas/water contact should be established, and in the Tilje Formation the oil/water and gas/oil contacts should be established or confirmed.
    Operations and results
    Appraisal well 6506/12-8 was spudded with the semi-submersible installation West Delta on 4 June 1988 and drilled to TD at 4334 m in the Early Jurassic Tilje Formation. The well was drilled without significant problems or incidents. It was drilled with spud mud down to 558 m, with gypsum polymer mud from 558 m to 3877 m, and with gel/lignosulphonate/lignite from 3877 m to TD. Gas bearing shallow sands were penetrated at 571 to 573 m and at 881 to 885 m.
    Weak shows were recorded in sands in the Lysing Formation at 3158 - 3185 m. Top of the target reservoir (top Garn Formation) was encountered at 3875 m, the Ile Formation was encountered at 3992.5 m, and the Tilje Formation was encountered at 4186 m. The logs showed good reservoir properties, especially in the Garn Formation. The Garn and the Tilje Formations were tested and found hydrocarbon bearing. The Garn Formation was hydrocarbon bearing all through down to the tight sandstones/siltstones of the Not Formation. Weak shows were recorded also in the Ile Formation sandstone, and the logs indicated hydrocarbons down to top Ror Formation at 4065 m. However, no test was conducted in the Ile Formation. In the Tilje Formation geochemical analyses of the cores showed that the hydrocarbons were distributed in distinct zones within the reservoir. The most likely OWC was estimated at ca 4269 m, but no clear contact was found.
    Eight cores were cut in the well. One core was cut in a claystone interval from 2311 -2321 m in the Tertiary Tang Formation, but it was not recovered to the surface. The remaining seven cores recovered a total of 208.8 m core. Five cores were cut in the interval 3878 - 4038.5 m (Fangst Group), and two cores were cut in the interval 4235 - 4292 m in the Tilje Formation. RFT fluid samples were taken at 3921 m (Garn), 3925 m (Garn), 3948.3 m (Garn), and at 4264 m (Tilje). The well was suspended on 1 September 1988 as an oil and gas appraisal well.
    Testing
    Two DST tests were performed.
    DST 1 tested the intervals 4205 - 4221 m and 4237 - 4277 m in the Tilje Formation. It produced 460 Sm3 oil, 115000 Sm3 gas and 8 - 10% water/d through a 28/64" choke. The GOR was 250 Sm3/Sm3, the oil density was 0.820 g/cm3, and the gas gravity was 0.820 (air = 1). The maximum bottom hole temperature was 148 deg C.
    DST 2 tested the intervals 3915 - 3923 m and 3934 - 3955 m in the Garn Formation. It produced 1420 Sm3 oil, 460000 Sm3 gas and no water/d through a 64/64" choke. The GOR was 324 Sm3/Sm3, the oil density was 0.830 g/cm3, and the gas gravity was 0.775 (air = 1). The maximum bottom hole temperature was 138 deg C.
  • Cuttings at the Norwegian Offshore Directorate

    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    560.00
    4335.00
  • 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
    3878.0
    3904.8
    [m ]
    3
    3905.0
    3941.2
    [m ]
    4
    3941.0
    3972.2
    [m ]
    5
    3973.0
    3995.8
    [m ]
    6
    4003.0
    4036.8
    [m ]
    7
    4235.0
    4258.6
    [m ]
    8
    4258.6
    4293.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    208.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 3878-3883m
    Core photo at depth: 3883-3888m
    Core photo at depth: 3888-3893m
    Core photo at depth: 3893-3898m
    Core photo at depth: 3898-3903m
    3878-3883m
    3883-3888m
    3888-3893m
    3893-3898m
    3898-3903m
    Core photo at depth: 3903-3904m
    Core photo at depth: 3905-3910m
    Core photo at depth: 3910-3915m
    Core photo at depth: 3915-2920m
    Core photo at depth: 3920-3925m
    3903-3904m
    3905-3910m
    3910-3915m
    3915-2920m
    3920-3925m
    Core photo at depth: 3925-3930m
    Core photo at depth: 3930-3935m
    Core photo at depth: 3935-3940m
    Core photo at depth: 3940-3941m
    Core photo at depth: 3941-3946m
    3925-3930m
    3930-3935m
    3935-3940m
    3940-3941m
    3941-3946m
    Core photo at depth: 3946-3951m
    Core photo at depth: 3951-3956m
    Core photo at depth: 3956-3961m
    Core photo at depth: 3961-3966m
    Core photo at depth: 3966-3971m
    3946-3951m
    3951-3956m
    3956-3961m
    3961-3966m
    3966-3971m
    Core photo at depth: 3971-3972m
    Core photo at depth: 3973-3978m
    Core photo at depth: 3978-3983m
    Core photo at depth: 3983-3988m
    Core photo at depth: 3988-3993m
    3971-3972m
    3973-3978m
    3978-3983m
    3983-3988m
    3988-3993m
    Core photo at depth: 3993-3995m
    Core photo at depth: 4003-4008m
    Core photo at depth: 4008-4013m
    Core photo at depth: 4013-4018m
    Core photo at depth: 4018-4023m
    3993-3995m
    4003-4008m
    4008-4013m
    4013-4018m
    4018-4023m
    Core photo at depth: 4023-4028m
    Core photo at depth: 4028-4033m
    Core photo at depth: 4033-4036m
    Core photo at depth: 4235-4240m
    Core photo at depth: 4240-4245m
    4023-4028m
    4028-4033m
    4033-4036m
    4235-4240m
    4240-4245m
    Core photo at depth: 4245-4250m
    Core photo at depth: 4250-4255m
    Core photo at depth: 4255-4258m
    Core photo at depth: 4258-4263m
    Core photo at depth: 4263-4268m
    4245-4250m
    4250-4255m
    4255-4258m
    4258-4263m
    4263-4268m
    Core photo at depth: 4268-4273m
    Core photo at depth: 4273-4278m
    Core photo at depth: 4278-4283m
    Core photo at depth: 4283-4288m
    Core photo at depth: 4288-4293m
    4268-4273m
    4273-4278m
    4278-4283m
    4283-4288m
    4288-4293m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2000.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2218.0
    [m]
    DC
    RRI
    2236.0
    [m]
    DC
    RRI
    2254.0
    [m]
    DC
    RRI
    2272.0
    [m]
    DC
    RRI
    2299.0
    [m]
    DC
    RRI
    2311.0
    [m]
    DC
    RRI
    2326.0
    [m]
    DC
    RRI
    2344.0
    [m]
    DC
    RRI
    2362.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2398.0
    [m]
    DC
    RRI
    2416.0
    [m]
    DC
    RRI
    2434.0
    [m]
    DC
    RRI
    2452.0
    [m]
    DC
    RRI
    2497.0
    [m]
    DC
    RRI
    2515.0
    [m]
    DC
    RRI
    2533.0
    [m]
    DC
    RRI
    2551.0
    [m]
    DC
    RRI
    2569.0
    [m]
    DC
    RRI
    2587.0
    [m]
    DC
    RRI
    2605.0
    [m]
    DC
    RRI
    2623.0
    [m]
    DC
    RRI
    2641.0
    [m]
    DC
    RRI
    2659.0
    [m]
    DC
    RRI
    2677.0
    [m]
    DC
    RRI
    2695.0
    [m]
    DC
    RRI
    2704.0
    [m]
    DC
    RRI
    2718.0
    [m]
    DC
    RRI
    2722.0
    [m]
    DC
    RRI
    2740.0
    [m]
    DC
    RRI
    2755.0
    [m]
    DC
    RRI
    2773.0
    [m]
    DC
    RRI
    2788.0
    [m]
    DC
    RRI
    2803.0
    [m]
    DC
    RRI
    2818.0
    [m]
    DC
    RRI
    2833.0
    [m]
    DC
    RRI
    2848.0
    [m]
    DC
    RRI
    2863.0
    [m]
    DC
    RRI
    2878.0
    [m]
    DC
    RRI
    2893.0
    [m]
    DC
    RRI
    2908.0
    [m]
    DC
    RRI
    2923.0
    [m]
    DC
    RRI
    2938.0
    [m]
    DC
    RRI
    2953.0
    [m]
    DC
    RRI
    2968.0
    [m]
    DC
    RRI
    2983.0
    [m]
    DC
    RRI
    2998.0
    [m]
    DC
    RRI
    3013.0
    [m]
    DC
    RRI
    3028.0
    [m]
    DC
    RRI
    3043.0
    [m]
    DC
    RRI
    3058.0
    [m]
    DC
    RRI
    3073.0
    [m]
    DC
    RRI
    3088.0
    [m]
    DC
    RRI
    3103.0
    [m]
    DC
    RRI
    3118.0
    [m]
    DC
    RRI
    3133.0
    [m]
    DC
    RRI
    3148.0
    [m]
    DC
    RRI
    3163.0
    [m]
    DC
    RRI
    3178.0
    [m]
    DC
    RRI
    3193.0
    [m]
    DC
    RRI
    3208.0
    [m]
    DC
    RRI
    3223.0
    [m]
    DC
    RRI
    3238.0
    [m]
    DC
    RRI
    3253.0
    [m]
    DC
    RRI
    3268.0
    [m]
    DC
    RRI
    3283.0
    [m]
    DC
    RRI
    3298.0
    [m]
    DC
    RRI
    3313.0
    [m]
    DC
    RRI
    3328.0
    [m]
    DC
    RRI
    3340.0
    [m]
    DC
    RRI
    3358.0
    [m]
    DC
    RRI
    3373.0
    [m]
    DC
    RRI
    3388.0
    [m]
    DC
    RRI
    3403.0
    [m]
    DC
    RRI
    3418.0
    [m]
    DC
    RRI
    3433.0
    [m]
    DC
    RRI
    3448.0
    [m]
    DC
    RRI
    3463.0
    [m]
    DC
    RRI
    3478.0
    [m]
    DC
    RRI
    3493.0
    [m]
    DC
    RRI
    3508.0
    [m]
    DC
    RRI
    3523.0
    [m]
    DC
    RRI
    3538.0
    [m]
    DC
    RRI
    3553.0
    [m]
    DC
    RRI
    3568.0
    [m]
    DC
    RRI
    3583.0
    [m]
    DC
    RRI
    3598.0
    [m]
    DC
    RRI
    3613.0
    [m]
    DC
    RRI
    3628.0
    [m]
    DC
    RRI
    3643.0
    [m]
    DC
    RRI
    3658.0
    [m]
    DC
    RRI
    3673.0
    [m]
    DC
    RRI
    3688.0
    [m]
    DC
    RRI
    3703.0
    [m]
    DC
    RRI
    3733.0
    [m]
    DC
    RRI
    3748.0
    [m]
    DC
    RRI
    3763.0
    [m]
    DC
    RRI
    3778.0
    [m]
    DC
    RRI
    3793.0
    [m]
    DC
    RRI
    3808.0
    [m]
    DC
    RRI
    3823.0
    [m]
    DC
    RRI
    3838.0
    [m]
    DC
    RRI
    3853.0
    [m]
    DC
    RRI
    3868.0
    [m]
    DC
    RRI
    4045.0
    [m]
    DC
    RRI
    4075.0
    [m]
    DC
    RRI
    4090.0
    [m]
    DC
    RRI
    4105.0
    [m]
    DC
    RRI
    4120.0
    [m]
    DC
    RRI
    4135.0
    [m]
    DC
    RRI
    4150.0
    [m]
    DC
    RRI
    4165.0
    [m]
    DC
    RRI
    4180.0
    [m]
    DC
    RRI
    4195.0
    [m]
    DC
    RRI
    4210.0
    [m]
    DC
    RRI
    4225.0
    [m]
    DC
    RRI
    4242.5
    [m]
    C
    RRI
    4258.1
    [m]
    C
    RRI
    4266.5
    [m]
    C
    RRI
    4273.8
    [m]
    C
    RRI
    4303.0
    [m]
    DC
    RRI
    4333.0
    [m]
    DC
    RRI
  • 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
    TEST1
    4237.00
    4277.00
    16.08.1988 - 05:00
    YES
    DST
    TEST2
    3915.00
    3923.00
    25.08.1988 - 01:00
    YES
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.27
    pdf
    2.24
    pdf
    2.25
    pdf
    0.19
  • 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
    12.33
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4237
    4277
    22.2
    1.2
    4205
    4221
    11.1
    2.0
    3915
    3955
    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
    1.2
    2.0
    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
    1100
    300000
    0.810
    0.827
    273
    1.2
    460
    115000
    0.820
    0.820
    250
    2.0
    610
    180000
    0.829
    0.756
    295
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    325
    1858
    CBL VDL GR
    3100
    3856
    CBL VDL GR
    3664
    4285
    CDL CN GR CAL
    1858
    3873
    CDL CN SPL
    3856
    4332
    DIFL AC GR
    1858
    3873
    DIFL AC GR 3CAL
    3856
    4331
    DIFL AC GR CDL CAL
    553
    1872
    DIPLOG
    3856
    4328
    FMT GR
    3179
    3179
    FMT HP
    3856
    4258
    MLL DLL GR
    3856
    4332
    MLL DLL GR CAL
    3092
    3240
    MWD - GR RES DIR
    386
    4335
    SPL
    4180
    4275
    VELOCITY
    1000
    4333
  • 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
    386.0
    36
    386.0
    0.00
    LOT
    SURF.COND.
    20
    553.0
    26
    577.0
    1.43
    LOT
    INTERM.
    13 3/8
    1859.0
    17 1/2
    1876.0
    1.83
    LOT
    INTERM.
    9 5/8
    3858.0
    12 1/4
    3877.0
    1.75
    LOT
    LINER
    7
    4332.0
    8 1/2
    4335.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    390
    1.04
    120.0
    WATER BASED
    06.06.1988
    390
    1.03
    WATER BASED
    06.06.1988
    571
    1.03
    WATER BASED
    08.06.1988
    571
    1.20
    8.0
    2.0
    WATER BASED
    10.06.1988
    577
    1.70
    WATER BASED
    07.06.1988
    981
    1.20
    45.0
    5.0
    WATER BASED
    13.06.1988
    1406
    1.30
    48.0
    3.5
    WATER BASED
    13.06.1988
    1579
    1.30
    14.0
    4.0
    WATER BASED
    13.06.1988
    1873
    1.35
    17.0
    5.5
    WATER BASED
    15.06.1988
    1873
    1.35
    17.0
    6.0
    WATER BASED
    14.06.1988
    1873
    1.70
    21.0
    2.5
    WATER BASED
    20.06.1988
    1876
    1.70
    58.0
    3.0
    WATER BASED
    20.06.1988
    1941
    1.70
    8.0
    14.5
    WATER BASED
    21.06.1988
    2311
    1.60
    28.0
    3.0
    WATER BASED
    24.06.1988
    2311
    1.60
    28.0
    3.0
    WATER BASED
    27.06.1988
    2530
    1.65
    23.0
    11.0
    WATER BASED
    06.07.1988
    2530
    1.63
    35.0
    8.0
    WATER BASED
    27.06.1988
    2530
    1.63
    24.0
    8.0
    WATER BASED
    27.06.1988
    2530
    1.63
    26.0
    10.0
    WATER BASED
    28.06.1988
    2530
    1.65
    28.0
    9.0
    WATER BASED
    29.06.1988
    3180
    1.65
    24.0
    9.0
    WATER BASED
    01.07.1988
    3398
    1.65
    23.0
    9.5
    WATER BASED
    04.07.1988
    3398
    1.65
    22.0
    10.5
    WATER BASED
    05.07.1988
    3620
    1.65
    19.0
    10.5
    WATER BASED
    07.07.1988
    3620
    1.65
    24.0
    9.0
    WATER BASED
    08.07.1988
    3669
    1.65
    26.0
    9.5
    WATER BASED
    11.07.1988
    3738
    1.65
    25.0
    10.0
    WATER BASED
    11.07.1988
    3808
    1.65
    25.0
    7.5
    WATER BASED
    11.07.1988
    3850
    1.65
    27.0
    9.0
    WATER BASED
    12.07.1988
    3850
    1.65
    23.0
    8.0
    WATER BASED
    13.07.1988
    3865
    1.65
    24.0
    8.5
    WATER BASED
    14.07.1988
    3871
    1.67
    25.0
    6.5
    WATER BASED
    15.07.1988
    3877
    1.67
    27.0
    7.5
    WATER BASED
    19.07.1988
    3877
    1.67
    23.0
    5.5
    WATER BASED
    19.07.1988
    3877
    1.67
    22.0
    5.5
    WATER BASED
    19.07.1988
    3877
    1.67
    21.0
    5.0
    WATER BASED
    19.07.1988
    3877
    1.67
    21.0
    6.5
    WATER BASED
    21.07.1988
    3877
    1.15
    33.0
    4.5
    WATER BASED
    29.07.1988
    3877
    1.15
    33.0
    4.5
    WATER BASED
    01.08.1988
    3877
    1.15
    33.0
    5.0
    WATER BASED
    03.08.1988
    3877
    1.15
    17.0
    2.5
    WATER BASED
    15.08.1988
    3877
    1.15
    13.0
    3.5
    WATER BASED
    23.08.1988
    3877
    1.15
    30.0
    11.5
    WATER BASED
    29.08.1988
    3877
    1.15
    32.0
    4.5
    WATER BASED
    27.07.1988
    3877
    1.15
    34.0
    6.0
    WATER BASED
    27.07.1988
    3877
    1.15
    37.0
    5.0
    WATER BASED
    27.07.1988
    3877
    1.15
    32.0
    3.5
    WATER BASED
    28.07.1988
    3877
    1.15
    38.0
    4.0
    WATER BASED
    01.08.1988
    3877
    1.15
    32.0
    4.0
    WATER BASED
    01.08.1988
    3877
    1.15
    40.0
    4.0
    WATER BASED
    04.08.1988
    3877
    1.15
    35.0
    4.0
    WATER BASED
    05.08.1988
    3877
    1.15
    33.0
    3.0
    WATER BASED
    08.08.1988
    3877
    1.15
    35.0
    15.5
    WATER BASED
    08.08.1988
    3877
    1.15
    35.0
    10.0
    WATER BASED
    08.08.1988
    3877
    1.15
    50.0
    12.5
    WATER BASED
    09.08.1988
    3877
    1.15
    23.0
    2.0
    WATER BASED
    11.08.1988
    3877
    1.15
    17.0
    2.5
    WATER BASED
    12.08.1988
    3877
    1.15
    11.0
    WATER BASED
    15.08.1988
    3877
    1.15
    11.0
    4.0
    WATER BASED
    15.08.1988
    3877
    1.15
    15.0
    3.5
    WATER BASED
    16.08.1988
    3877
    1.15
    18.5
    2.5
    WATER BASED
    19.08.1988
    3877
    1.16
    16.0
    3.0
    WATER BASED
    19.08.1988
    3877
    1.15
    6.0
    2.5
    WATER BASED
    22.08.1988
    3877
    1.15
    12.0
    3.0
    WATER BASED
    24.08.1988
    3877
    1.15
    11.0
    3.0
    WATER BASED
    25.08.1988
    3877
    1.15
    17.0
    4.5
    WATER BASED
    26.08.1988
    3877
    1.15
    34.0
    11.5
    WATER BASED
    29.08.1988
    3877
    1.15
    39.0
    9.5
    WATER BASED
    29.08.1988
    3877
    0.00
    WATER BASED
    30.08.1988
    3878
    1.15
    12.0
    2.5
    WATER BASED
    21.07.1988
    3905
    1.15
    15.0
    2.5
    WATER BASED
    27.07.1988
    3918
    1.15
    26.0
    2.5
    WATER BASED
    27.07.1988
    3983
    1.15
    27.0
    4.0
    WATER BASED
    27.07.1988
  • 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