Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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35/3-2

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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.
    35/3-2
    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
    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.
    35/3-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    TLGS 78-01 SP.2945
    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.
    Saga Petroleum ASA
    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.
    249-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.
    161
    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,
    19.05.1980
    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.
    26.10.1980
    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.
    26.10.1982
    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.
    18.05.2004
    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.
    GAS/CONDENSATE
    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.
    EARLY CRETACEOUS
    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.
    AGAT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    272.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4400.0
    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).
    4396.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    147
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 51' 5.98'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 46' 28.22'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6858062.65
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    540764.96
    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.
    136

  • Wellbore history
    General
    Whereas Saga Petroleum operated license 041, BP operated wildcat well 35/3-2 under license 041 by special agreement. The well was the second well drilled on this block, 35/3-1 was abandoned in the Middle Jurassic due to high calculated pore pressures. Well 35/3-2 was drilled on a westerly dipping fault block. The primary target of the well was Early Jurassic sandstone, secondary targets were any other Jurassic sandstones encountered.
    Operations and results
    Wildcat well 35/3-2 was spudded with the semi-submersible installation Sedco 707 on 19 May 1980 and drilled to TD at 4400 m in ?Caledonian age basement rocks. The well was drilled with seawater and gel down to 902 m, with gypsum/CMC mud from 902 m to 2305 m, with Poly RX/Drispac from 2305 m to 3833m, and with Poly RX/Lignosulfonate mud from 3833 m to TD. The well started to flow while drilling the 24" hole.  Heavy mud was pumped down the hole, but there was very little difference between the fracture gradient and the bottom hole pressure and returns were lost several times. A loss/gain situation was maintained until the casing setting depth was reached. When running the 18 5/8" casing the string parted and 22 joints were left in the hole.  The string was recovered successfully, and a new string was run and cemented without problems.
    The well penetrated strata from Tertiary through Jurassic and Triassic before reaching basement. Hydrocarbon shows were encountered in Lower Cretaceous and Lower Jurassic sands. The primary target Jurassic sandstones were found to be very tight, and no DST was carried out in these. In stead two zones in the Lower Cretaceous Sandstone were tested, producing water and gas/condensate respectively. The lower Cretaceous sands are interpreted as submarine fan deposits. The Lower Jurassic coarsening upward sequences may represent offshore open marine bars cut by tidal channel deposits and capped by a transgressive marine sheet sand. Log evaluation indicated 13.7 meters net pay in the Lower Cretaceous, with an average porosity of 15 % and an average water saturation of 64.3 %. The RFT pressure gradients suggested that a gas-water contact exists at 3585 m. Log interpretation showed moveable hydrocarbons to 3588.5 m and formation water below 3591 m. A possible 8.8 meters of net hydrocarbon bearing thin sand stringers were penetrated in the Lower Jurassic sequence.
    Two FIT fluid samples were taken through the 9 5/8" casing. The first FIT was run at 3675.5 m. Total recovery was 1 litre of gas and 22 litres of flocculated mud with trace of oil. The second FIT was run at 3750.5 m. Total recovery was 1 litre of mud filtrate/water and 10 litres of flocculated mud. This sample had no measurable gas volume. Two RFT segregated samples were taken in the Early Cretaceous Agat Formation. A segregated sample was collected in the gas-bearing interval at 3565.5 m, and both chambers were found to contain gas only with no trace of mud filtrate. The second sample collected in the water-bearing interval at 3593 m recovered 7.5 litres of water and 13.1 litres of gas in the 2-3/4 gallon chamber, and 3.8 litres of water with 3.4 litres of gas in the 1-gallon chamber. Analysis of the water samples indicated that mud filtrate had been recovered. RFT sampling in the Early Jurassic at 4073 m, 4024.5 m, and 3939 m was unsuccessful and recovered only mud filtrate and water. Seven cores were cut in the well. Cores 1 to 4 were cut in the Agat Formation from 3593.3 m to 3641 m, core 5 was cut in the Agat Formation from 3690.7 m to 3708.3 m, core 6 was cut in the Lower Jurassic from 3944.5 m to 3960 m, and core 7 was cut in the Lower Jurassic from 3998.2 m to 4010 m.
    The well was plugged and abandoned as a gas/condensate discovery (Agat) on October 1980.
    Testing
    Two drill stem tests were carried out in the Early Cretaceous Agat Formation. DST1 perforated the interval 3599 m to 3605 m. This test produced water at a rate of 555 Sm3/day through a 38/64" choke. The gas dissolved in the water showed no H2S and only traces of C02. DST2 perforated the intervals 3547 m to 3552, 3555.5 m to 3558, and 3562 m to 3566 m. It produced 1082000 Sm3 gas/day through a 38/64" choke. The final flow rate with the choke at 32/64 was 736000 Sm3/day. Because of a failure on the condensate metering system on the separator condensate flow rates were measured by flowtank dipping. A final condensate/gas ratio of approximately 10 bbl/MMSCF (5.6 x 10-5 Sm3/Sm3, corresponding to GOR = 18000 Sm3/Sm3) has been estimated. The gas gravity was 0.62 (air =1) and the condensate density was 0.815 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]
    470.00
    4400.00

  • 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
    1
    3593.2
    3610.8
    [m ]
    2
    3611.0
    3613.3
    [m ]
    3
    3613.3
    3617.3
    [m ]
    4
    3625.0
    3641.0
    [m ]
    5
    3690.7
    3710.2
    [m ]
    6
    3944.5
    3960.4
    [m ]
    7
    3998.2
    4010.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    87.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3593-3596m
    Core photo at depth: 3596-3598m
    Core photo at depth: 3598-3601m
    Core photo at depth: 3601-3604m
    Core photo at depth: 3604-3606m
    3593-3596m
    3596-3598m
    3598-3601m
    3601-3604m
    3604-3606m
    Core photo at depth: 3606-3609m
    Core photo at depth: 3609-3610m
    Core photo at depth: 3611-3614m
    Core photo at depth: 3613-3616m
    Core photo at depth: 3616-2617m
    3606-3609m
    3609-3610m
    3611-3614m
    3613-3616m
    3616-2617m
    Core photo at depth: 3625-3627m
    Core photo at depth: 3627-3630m
    Core photo at depth: 3630-3633m
    Core photo at depth: 3633-3635m
    Core photo at depth: 3635-3638m
    3625-3627m
    3627-3630m
    3630-3633m
    3633-3635m
    3635-3638m
    Core photo at depth: 3638-3641m
    Core photo at depth: 3690-3693m
    Core photo at depth: 3693-3696m
    Core photo at depth: 3696-3698m
    Core photo at depth: 3698-3701m
    3638-3641m
    3690-3693m
    3693-3696m
    3696-3698m
    3698-3701m
    Core photo at depth: 3701-3704m
    Core photo at depth: 3704-3706m
    Core photo at depth: 3706-3709m
    Core photo at depth: 3709-3710m
    Core photo at depth: 3944-3947m
    3701-3704m
    3704-3706m
    3706-3709m
    3709-3710m
    3944-3947m
    Core photo at depth: 3947-3949m
    Core photo at depth: 3949-3952m
    Core photo at depth: 3952-3955m
    Core photo at depth: 3955-3958m
    Core photo at depth: 3958-3960m
    3947-3949m
    3949-3952m
    3952-3955m
    3955-3958m
    3958-3960m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    800.0
    [m]
    DC
    OD
    900.0
    [m]
    DC
    OD
    1000.0
    [m]
    DC
    OD
    1200.0
    [m]
    DC
    OD
    1400.0
    [m]
    DC
    OD
    1500.0
    [m]
    DC
    OD
    1520.0
    [m]
    DC
    OD
    1540.0
    [m]
    DC
    OD
    1560.0
    [m]
    DC
    OD
    1650.0
    [m]
    DC
    OD
    1680.0
    [m]
    DC
    OD
    1700.0
    [m]
    DC
    OD
    1900.0
    [m]
    DC
    OD
    2100.0
    [m]
    DC
    OD
    2300.0
    [m]
    DC
    OD
    2500.0
    [m]
    DC
    OD
    2700.0
    [m]
    DC
    OD
    2900.0
    [m]
    DC
    OD
    2950.0
    [m]
    DC
    OD
    3000.0
    [m]
    DC
    OD
    3180.0
    [m]
    DC
    OD
    3200.0
    [m]
    DC
    OD
    3250.0
    [m]
    DC
    OD
    3300.0
    [m]
    DC
    OD
    3500.0
    [m]
    DC
    OD
    3593.0
    [m]
    DC
    OD
    3593.8
    [m]
    C
    OD
    3594.6
    [m]
    C
    OD
    3595.7
    [m]
    C
    OD
    3596.7
    [m]
    C
    OD
    3597.7
    [m]
    C
    OD
    3598.6
    [m]
    C
    OD
    3599.6
    [m]
    C
    OD
    3600.9
    [m]
    C
    OD
    3601.8
    [m]
    C
    OD
    3602.8
    [m]
    C
    OD
    3603.9
    [m]
    C
    OD
    3604.7
    [m]
    C
    OD
    3605.8
    [m]
    C
    OD
    3606.8
    [m]
    C
    OD
    3607.9
    [m]
    C
    OD
    3608.9
    [m]
    C
    OD
    3609.9
    [m]
    C
    OD
    3611.4
    [m]
    C
    OD
    3612.5
    [m]
    C
    OD
    3613.6
    [m]
    C
    OD
    3614.7
    [m]
    C
    OD
    3615.2
    [m]
    C
    OD
    3616.1
    [m]
    C
    OD
    3616.9
    [m]
    C
    ROBERTSO
    3623.0
    [m]
    DC
    OD
    3625.0
    [m]
    C
    OD
    3626.0
    [m]
    C
    OD
    3626.8
    [m]
    C
    ROBERTSO
    3627.7
    [m]
    C
    OD
    3628.1
    [m]
    C
    OD
    3629.2
    [m]
    C
    OD
    3629.5
    [m]
    C
    OD
    3629.5
    [m]
    C
    OD
    3630.0
    [m]
    C
    ROBERTSO
    3630.0
    [m]
    C
    OD
    3631.6
    [m]
    C
    OD
    3632.8
    [m]
    C
    OD
    3633.0
    [m]
    C
    ROBERTSO
    3634.1
    [m]
    C
    OD
    3635.5
    [m]
    C
    OD
    3636.3
    [m]
    C
    ROBERTSO
    3637.3
    [m]
    C
    OD
    3638.4
    [m]
    C
    OD
    3639.5
    [m]
    C
    ROBERTSO
    3640.8
    [m]
    C
    OD
    3690.8
    [m]
    C
    ROBERTSO
    3692.3
    [m]
    C
    OD
    3692.3
    [m]
    C
    OD
    3693.5
    [m]
    C
    OD
    3694.0
    [m]
    C
    ROBERTSO
    3695.0
    [m]
    C
    OD
    3696.0
    [m]
    C
    OD
    3697.0
    [m]
    C
    ROBERTSO
    3697.7
    [m]
    C
    OD
    3697.8
    [m]
    C
    OD
    3698.0
    [m]
    C
    OD
    3698.8
    [m]
    C
    OD
    3699.3
    [m]
    C
    OD
    3700.0
    [m]
    C
    OD
    3700.0
    [m]
    C
    ROBERTSO
    3700.8
    [m]
    C
    OD
    3701.8
    [m]
    C
    OD
    3702.9
    [m]
    C
    OD
    3703.9
    [m]
    C
    OD
    3704.0
    [m]
    C
    ROBERTSO
    3705.0
    [m]
    C
    OD
    3706.0
    [m]
    C
    OD
    3707.0
    [m]
    C
    OD
    3708.0
    [m]
    C
    ROBERTSO
    3710.0
    [m]
    C
    OD
    3710.0
    [m]
    DC
    OD
    3710.1
    [m]
    C
    ROBERTSO
    3800.0
    [m]
    DC
    OD
    3821.0
    [m]
    DC
    OD
    3839.0
    [m]
    DC
    OD
    3860.0
    [m]
    DC
    OD
    3902.0
    [m]
    DC
    OD
    3945.0
    [m]
    C
    OD
    3946.2
    [m]
    C
    OD
    3947.7
    [m]
    C
    OD
    3948.9
    [m]
    C
    OD
    3950.0
    [m]
    C
    OD
    3950.0
    [m]
    DC
    OD
    3950.9
    [m]
    C
    OD
    3952.0
    [m]
    C
    OD
    3953.2
    [m]
    C
    OD
    3954.3
    [m]
    C
    OD
    3955.8
    [m]
    C
    OD
    3956.9
    [m]
    C
    OD
    3957.9
    [m]
    C
    OD
    3958.9
    [m]
    C
    OD
    3960.2
    [m]
    C
    OD
    3998.2
    [m]
    C
    OD
    3999.4
    [m]
    C
    OD
    4000.0
    [m]
    C
    OD
    4001.0
    [m]
    C
    OD
    4001.0
    [m]
    DC
    OD
    4002.2
    [m]
    C
    OD
    4003.2
    [m]
    C
    OD
    4004.4
    [m]
    C
    OD
    4005.3
    [m]
    C
    OD
    4007.0
    [m]
    C
    OD
    4007.9
    [m]
    C
    OD
    4008.6
    [m]
    C
    OD
    4009.7
    [m]
    C
    OD

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.73

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.18
    pdf
    1.34
    pdf
    0.57
    pdf
    1.95
    pdf
    1.95
    pdf
    1.94

  • 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
    15.35

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3599
    3605
    15.0
    2.0
    3552
    3566
    15.0
    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
    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
    53
    1082000
    0.819
    0.620

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    0
    0
    CBL CCL
    296
    1020
    CBL VDL CCL GR
    3400
    3821
    CST
    3300
    3834
    DLL GR
    3821
    4397
    DLL MSFL GR
    3450
    3834
    FDC CNL GR
    3450
    3834
    FDC CNL GR
    3821
    4125
    FDC CNL GR
    4401
    4425
    HDT
    3300
    3834
    HDT
    3300
    3834
    HDT
    3821
    4401
    HRT CCL
    0
    2350
    HRT CCL
    250
    841
    HRT CCL
    285
    990
    ISF BHC MSFL GR SP CAL
    4124
    4400
    ISF BHCS MSFL GR SP CAL
    3821
    4124
    ISF BHCS MSFL SP GR CAL
    250
    2305
    ISF BHCS MSFL SP GR CAL
    2287
    3834

  • 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
    430.0
    36
    436.0
    0.00
    LOT
    SURF.COND.
    18 5/8
    868.0
    24
    875.0
    0.00
    LOT
    INTERM.
    13 3/8
    2262.0
    17 1/2
    2280.0
    0.00
    LOT
    INTERM.
    9 5/8
    3797.0
    12 1/4
    3808.0
    1.63
    LOT
    LINER
    7
    4400.0
    8 3/8
    4400.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    662
    0.00
    seawater
    900
    1.08
    watermud
    1522
    1.10
    watermud
    2290
    1.23
    43.0
    watermud
    2603
    1.32
    53.0
    watermud
    3090
    1.34
    50.0
    watermud
    3575
    1.42
    54.0
    watermud
    3617
    1.42
    52.0
    watermud
    3833
    1.47
    55.0
    watermud
    4400
    1.57
    58.0
    watermud

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3593.75
    [m ]
    3594.55
    [m ]
    3595.70
    [m ]
    3596.65
    [m ]
    3597.65
    [m ]
    3598.60
    [m ]
    3599.60
    [m ]
    3600.85
    [m ]
    3601.80
    [m ]
    3602.80
    [m ]
    3603.90
    [m ]
    3604.65
    [m ]
    3605.75
    [m ]
    3606.75
    [m ]
    3607.90
    [m ]
    3608.90
    [m ]
    3609.90
    [m ]
    3611.40
    [m ]
    3612.45
    [m ]
    3613.60
    [m ]
    3614.68
    [m ]
    3615.20
    [m ]
    3616.10
    [m ]
    3625.00
    [m ]
    3625.98
    [m ]
    3628.10
    [m ]
    3629.20
    [m ]
    3629.45
    [m ]
    3629.50
    [m ]
    3632.82
    [m ]
    3637.25
    [m ]
    3692.25
    [m ]
    3692.30
    [m ]
    3693.50
    [m ]
    3695.00
    [m ]
    3696.00
    [m ]
    3697.70
    [m ]
    3697.75
    [m ]
    3698.00
    [m ]
    3698.75
    [m ]
    3699.30
    [m ]
    3700.75
    [m ]
    3702.85
    [m ]
    3703.85
    [m ]
    3704.95
    [m ]
    3705.95
    [m ]
    3706.95
    [m ]
    3747.70
    [m ]
    3748.90
    [m ]
    3950.93
    [m ]
    3952.02
    [m ]
    3953.15
    [m ]
    3954.30
    [m ]
    3955.80
    [m ]
    3956.85
    [m ]
    3957.90
    [m ]
    3958.90
    [m ]
    3960.20
    [m ]
    3999.35
    [m ]
    4001.00
    [m ]
    4002.15
    [m ]
    4003.15
    [m ]
    4004.37
    [m ]
    4005.30
    [m ]
    4006.95
    [m ]
    4007.90
    [m ]
    4008.60
    [m ]
    4009.70
    [m ]

  • 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