Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15/12-9 S

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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.
    15/12-9 S
    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.
    RE-CLASS TO DEV
    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.
    15/12-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8802- KOLONNE 919 & RAD 461
    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.
    732-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.
    84
    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,
    17.07.1992
    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.
    08.10.1992
    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.
    08.10.1994
    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.
    06.01.2015
    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
    Reclassified to wellbore
    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.
    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.
    LATE 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.
    INTRA HEATHER FM SS
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    84.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3848.0
    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).
    3213.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    57.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    124
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 4' 40.43'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 53' 25.75'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6438067.06
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    434558.55
    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.
    1978

  • Wellbore history
    General
    Well 15/12-9 S was drilled on the Varg Field in the North Sea. The Varg Field reservoir is in Upper Jurassic sandstones at a depth of approximately 2700 metres. The Varg Field is segmented and includes several isolated compartments with varying reservoir properties. The well was drilled from a location near to the Varg A and Petrojarl A production installations and targeted a southern compartment in the Varg structure. The objective for the well was to prove hydrocarbons in Late Oxfordian sandstone and to reduce the uncertainty in the reserve estimate for this part of the Varg Field.
    Operations and results
    Appraisal well 15/12-9 S was spudded with the semi-submersible installation Deepsea Bergen on 17 July 1992 and drilled to TD at 3848 m (3213 m TVD) in the Triassic Skagerrak Formation. The well was drilled deviated from 623 m with a sail angle of ca 56 ° and then vertical again from ca 2400 m TVD through the target reservoir to TD. The well was drilled with seawater down to 620 m, with KCl/polymer mud from 620 mto 3226 m, and with Ancotemp/bentonite mud from 3226 m to TD.
    The well penetrated top reservoir, the Oxfordian sandstones, at 3385 m (2750 m TVD). The reservoir was oil-bearing down to a well-defined OWC at 3501.5 m (2867.0 m TVD). Seven cores were cut with 100% recovery. Core 1 to 6 were cut in the interval 3689 m to 3555 m and core 7 was cut from 3649.5 m to 3668.0 m. The core to log depth shift was -2.45 m for core 7; for the other cores the core depth was equal to the logger’s depth. Two segregated FMT oil samples were taken at 3498 m. Oil shows continued down to 3545m
    The well is classified an oil appraisal well. It was suspended on 8 October 1992 and was later re-classified to oil production well 15/12-A-11 on the Varg Field.
    Testing
    Two drill stem tests were performed in the Oxfordian sandstones.
    DST 1 tested the water zone from 3545 m to 3552 m (2910 – 2917 m). The test produced water at a rate of 890 m3/day through a 48/64” choke.
    DST 2 tested the oil zone from 3385 m to 3443 m (2750 – 2809 m). The test produced on average 132200 Sm3 gas and 1520 Sm3 oil /day through a 40/64” choke. The GOR was 87 Sm3/Sm3, the oil density was 0.852 g/cm3 and the gas gravity was 0.751 (air = 1) with 1.5% CO2 and 4% H2S. Maximum flowing temperature was 124.6 °C.

  • 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]
    630.00
    3815.00

  • 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
    3389.0
    3416.0
    [m ]
    2
    3416.0
    3443.6
    [m ]
    3
    3443.6
    3471.0
    [m ]
    4
    3471.3
    3499.0
    [m ]
    5
    3499.1
    3527.0
    [m ]
    6
    3527.3
    3555.0
    [m ]
    7
    3652.0
    3670.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    183.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3389-3394m
    Core photo at depth: 3394-3399m
    Core photo at depth: 3399-3404m
    Core photo at depth: 3404-3409m
    Core photo at depth: 3409-3414m
    3389-3394m
    3394-3399m
    3399-3404m
    3404-3409m
    3409-3414m
    Core photo at depth: 3414-3416m
    Core photo at depth: 3416-3421m
    Core photo at depth: 3421-3426m
    Core photo at depth: 3426-3431m
    Core photo at depth: 3431-3436m
    3414-3416m
    3416-3421m
    3421-3426m
    3426-3431m
    3431-3436m
    Core photo at depth: 3436-3441m
    Core photo at depth: 3441-3443m
    Core photo at depth: 3443-3448m
    Core photo at depth: 3448-3453m
    Core photo at depth: 3453-3458m
    3436-3441m
    3441-3443m
    3443-3448m
    3448-3453m
    3453-3458m
    Core photo at depth: 3458-3463m
    Core photo at depth: 3463-3468m
    Core photo at depth: 3468-3471m
    Core photo at depth: 3471-3476m
    Core photo at depth: 3476-3481m
    3458-3463m
    3463-3468m
    3468-3471m
    3471-3476m
    3476-3481m
    Core photo at depth: 3481-3486m
    Core photo at depth: 3486-3491m
    Core photo at depth: 3491-3496m
    Core photo at depth: 3496-3499m
    Core photo at depth: 3499-3504m
    3481-3486m
    3486-3491m
    3491-3496m
    3496-3499m
    3499-3504m
    Core photo at depth: 3504-3509m
    Core photo at depth: 3509-3514m
    Core photo at depth: 3514-3519m
    Core photo at depth: 3519-3524m
    Core photo at depth: 3524-3527m
    3504-3509m
    3509-3514m
    3514-3519m
    3519-3524m
    3524-3527m
    Core photo at depth: 3527-3532m
    Core photo at depth: 3532-3537m
    Core photo at depth: 3537-3542m
    Core photo at depth: 3542-3547m
    Core photo at depth: 3547-3552m
    3527-3532m
    3532-3537m
    3537-3542m
    3542-3547m
    3547-3552m
    Core photo at depth: 3553-3555m
    Core photo at depth: 3652-3657m
    Core photo at depth: 3657-3662m
    Core photo at depth: 3662-3667m
    Core photo at depth: 3667-3670m
    3553-3555m
    3652-3657m
    3657-3662m
    3662-3667m
    3667-3670m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1350.0
    [m]
    DC
    GEOCH
    1370.0
    [m]
    DC
    GEOCH
    1390.0
    [m]
    DC
    GEOCH
    1410.0
    [m]
    DC
    GEOCH
    1430.0
    [m]
    DC
    GEOCH
    1450.0
    [m]
    DC
    GEOCH
    1470.0
    [m]
    DC
    GEOCH
    1490.0
    [m]
    DC
    GEOCH
    1510.0
    [m]
    DC
    GEOCH
    1530.0
    [m]
    DC
    GEOCH
    1550.0
    [m]
    DC
    GEOCH
    1570.0
    [m]
    DC
    GEOCH
    1590.0
    [m]
    DC
    GEOCH
    1610.0
    [m]
    DC
    GEOCH
    1630.0
    [m]
    DC
    GEOCH
    1650.0
    [m]
    DC
    GEOCH
    1670.0
    [m]
    DC
    GEOCH
    1690.0
    [m]
    DC
    GEOCH
    1710.0
    [m]
    DC
    GEOCH
    1730.0
    [m]
    DC
    GEOCH
    1750.0
    [m]
    DC
    GEOCH
    1770.0
    [m]
    DC
    GEOCH
    1790.0
    [m]
    DC
    GEOCH
    1810.0
    [m]
    DC
    GEOCH
    1830.0
    [m]
    DC
    GEOCH
    1850.0
    [m]
    DC
    GEOCH
    1870.0
    [m]
    DC
    GEOCH
    1890.0
    [m]
    DC
    GEOCH
    1910.0
    [m]
    DC
    GEOCH
    1930.0
    [m]
    DC
    GEOCH
    1950.0
    [m]
    DC
    GEOCH
    1970.0
    [m]
    DC
    GEOCH
    1990.0
    [m]
    DC
    GEOCH
    2010.0
    [m]
    DC
    GEOCH
    2030.0
    [m]
    DC
    GEOCH
    2050.0
    [m]
    DC
    GEOCH
    2070.0
    [m]
    DC
    GEOCH
    2090.0
    [m]
    DC
    GEOCH
    2110.0
    [m]
    DC
    GEOCH
    2130.0
    [m]
    DC
    GEOCH
    2150.0
    [m]
    DC
    GEOCH
    2170.0
    [m]
    DC
    GEOCH
    2190.0
    [m]
    DC
    GEOCH
    2210.0
    [m]
    DC
    GEOCH
    2230.0
    [m]
    DC
    GEOCH
    2250.0
    [m]
    DC
    GEOCH
    2270.0
    [m]
    DC
    GEOCH
    2290.0
    [m]
    DC
    GEOCH
    2310.0
    [m]
    DC
    GEOCH
    2330.0
    [m]
    DC
    GEOCH
    2350.0
    [m]
    DC
    GEOCH
    2370.0
    [m]
    DC
    GEOCH
    2390.0
    [m]
    DC
    GEOCH
    2410.0
    [m]
    DC
    GEOCH
    2430.0
    [m]
    DC
    GEOCH
    2450.0
    [m]
    DC
    GEOCH
    2470.0
    [m]
    DC
    GEOCH
    2490.0
    [m]
    DC
    GEOCH
    2510.0
    [m]
    DC
    GEOCH
    2530.0
    [m]
    DC
    GEOCH
    2550.0
    [m]
    DC
    GEOCH
    2570.0
    [m]
    DC
    GEOCH
    2590.0
    [m]
    DC
    GEOCH
    2610.0
    [m]
    DC
    GEOCH
    2630.0
    [m]
    DC
    GEOCH
    2650.0
    [m]
    DC
    GEOCH
    2670.0
    [m]
    DC
    GEOCH
    2690.0
    [m]
    DC
    GEOCH
    2710.0
    [m]
    DC
    GEOCH
    2730.0
    [m]
    DC
    GEOCH
    2750.0
    [m]
    DC
    GEOCH
    2770.0
    [m]
    DC
    GEOCH
    2790.0
    [m]
    DC
    GEOCH
    2810.0
    [m]
    DC
    GEOCH
    2830.0
    [m]
    DC
    GEOCH
    2850.0
    [m]
    DC
    GEOCH
    2870.0
    [m]
    DC
    GEOCH
    2890.0
    [m]
    DC
    GEOCH
    2910.0
    [m]
    DC
    GEOCH
    2930.0
    [m]
    DC
    GEOCH
    2950.0
    [m]
    DC
    GEOCH
    2970.0
    [m]
    DC
    GEOCH
    2990.0
    [m]
    DC
    GEOCH
    3010.0
    [m]
    DC
    GEOCH
    3030.0
    [m]
    DC
    GEOCH
    3050.0
    [m]
    DC
    GEOCH
    3070.0
    [m]
    DC
    GEOCH
    3080.0
    [m]
    DC
    GEOCH
    3327.0
    [m]
    DC
    3371.0
    [m]
    DC
    3391.6
    [m]
    C
    3391.6
    [m]
    C
    3399.2
    [m]
    C
    STATOIL
    3438.1
    [m]
    C
    3447.6
    [m]
    C
    3454.3
    [m]
    C
    STATOIL
    3459.6
    [m]
    C
    3462.5
    [m]
    C
    STATOIL
    3478.8
    [m]
    C
    STATOI
    3490.4
    [m]
    C
    3509.3
    [m]
    C
    3526.4
    [m]
    C
    3554.4
    [m]
    C
    3654.4
    [m]
    C
    3661.0
    [m]
    C
    3661.2
    [m]
    C
    3669.2
    [m]
    C
    3707.0
    [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
    DST2
    3385.00
    0.00
    OIL
    28.09.1992 - 17:50
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.26
    pdf
    3.89
    pdf
    0.92

  • 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
    1.97
    pdf
    17.64

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3545
    0
    19.0
    2.0
    3385
    0
    20.6
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.000
    2.0
    100.000
    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
    1520
    0.852
    0.751
    87

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBIL HXDIP GR
    3350
    3700
    CBL VDL CCL GR
    2925
    3789
    CBL VDL GR
    1330
    2191
    CBL VDL GR
    2450
    3312
    CCL GR
    2930
    3360
    CST GR
    3318
    3833
    DIFL ACL ZDL CNL GR
    3306
    3844
    DLL MLL GR
    3306
    3676
    FMT GR
    3400
    3673
    HXDIP GR
    3306
    3848
    MWD
    175
    3848
    VSP
    1570
    3730

  • 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
    167.0
    36
    167.0
    0.00
    LOT
    INTERM.
    20
    599.0
    26
    600.0
    1.76
    LOT
    INTERM.
    13 3/8
    2207.0
    17 1/2
    2210.0
    1.91
    LOT
    INTERM.
    9 5/8
    3313.0
    12 1/4
    3315.0
    1.87
    LOT
    LINER
    5 1/2
    3846.0
    8 1/2
    3848.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    620
    1.03
    DUMMY
    620
    1.03
    WATER BASED
    623
    1.39
    34.0
    DUMMY
    960
    1.39
    40.0
    DUMMY
    1387
    1.39
    46.0
    DUMMY
    1697
    1.39
    46.0
    DUMMY
    2225
    1.39
    36.0
    WATER BASED
    2228
    1.39
    31.0
    WATER BASED
    2333
    1.33
    36.0
    WATER BASED
    2447
    1.39
    31.0
    WATER BASED
    2613
    1.50
    32.0
    WATER BASED
    2895
    1.53
    48.0
    WATER BASED
    3035
    1.53
    37.0
    WATER BASED
    3169
    1.53
    39.0
    WATER BASED
    3292
    1.53
    37.0
    WATER BASED
    3326
    1.53
    40.0
    WATER BASED
    3330
    1.33
    16.0
    WATER BASED
    3333
    1.33
    27.0
    WATER BASED
    3385
    1.33
    29.0
    WATER BASED
    3389
    1.33
    27.0
    WATER BASED
    3443
    1.33
    28.0
    WATER BASED
    3471
    1.33
    25.0
    WATER BASED
    3527
    1.33
    28.0
    WATER BASED
    3555
    1.33
    21.0
    WATER BASED
    3610
    1.33
    25.0
    WATER BASED
    3655
    1.33
    32.0
    WATER BASED
    3690
    1.33
    36.0
    WATER BASED
    3848
    1.33
    34.0
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3525.70
    [m ]
    3532.10
    [m ]
    3532.70
    [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