Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6407/7-2

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6407/7-2
    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).
    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.
    SUSPENDED
    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.
    6407/7-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8604 - 235 KOLONNE 960
    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.
    Norsk Hydro Produksjon 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.
    532-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.
    63
    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,
    19.11.1986
    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.
    21.01.1987
    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.
    21.01.1989
    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.
    09.03.2009
    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/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.
    ILE 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.
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    338.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3320.0
    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).
    3320.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    125
    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.
    LATE 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.
    RED BEDS (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 15' 26.39'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 10' 42.65'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7127130.16
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    411732.18
    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.
    1017

  • Wellbore history
    General
    Well 6407/7-2 was drilled on the Njord A-structure in the southern part of the Halten Terrace. The Njord structure is located ca 30 km west of the Draugen Field. The primary objectives of the well were to test the reservoir properties of the pre-Tilje sequence and to find the oil-water contact in the central part of the A-structure. By this the volumetric potential of the structure could be established. The well would furthermore obtain seismic calibration to the base Cretaceous and intra Jurassic and intra Triassic events. It should penetrate a flat seismic event at approximately 2570 ms TWT. A Rogn Formation sand unit was expected at 2598 +/- 65 m.
    Operations and results
    Well 6407/7-2 was spudded with the semi-submersible installation Polar Pioneer on 20 November 1986. The 36" hole was drilled to 361 m where the MWD showed an inclination of 7.1 degrees. A respud was thus decided. The well was respudded on 20 November and drilled without significant problems to TD at 3320 m in the Triassic Red Beds. It was drilled with spud mud down to 780 m and with KCl/polymer mud from 780 m to TD.
    No Rogn Formation was encountered. Hydrocarbons were encountered in two different pressured reservoir zones in the Middle to Early Jurassic. The upper reservoir was a 14 m gas/condensate zone in the Ile Formation from 2697.5 m to 2711.5 m. A segregated RFT sample from this zone recovered gas and condensate. The lower and main reservoir zone was encountered from 2771 to 2877.5 m in the Tilje Formation and contained oil. Two drill stem testes were performed in this zone. The Åre Formation was encountered at 2877.5 m and consisted of sandstones with minor claystones and siltstones. The Åre Formation sandstones were cemented and with low porosity. The logs and cores proved the Åre Formation to be water bearing, although moderate quality RFT pressure data gave an oil gradient in the interval 2896 to 2925 m.
    Eleven cores were cut in the well with a total recovery of 171.25 m (87%). The first core was cut in the interval 2673 - 2688 m, two cores in the interval 2701 - 2742 m, and 8 cores in the interval 2775 - 2915 m. A segregated RFT sample from 2701.9 m recovered 2.1 Sm3 gas, 1.85 l condensate, and 0.9 l filtrate.
    The well was suspended on 21 January 1987 as a possible future development well or for long term testing. It is classified as an oil appraisal well.
    Testing
    Two drill stem tests were performed in the Tilje Formation main reservoir.
    DST 1 in the interval 2869.8 - 2878.8 m produced 125 Sm3 oil and 23750 Sm3 gas /day through a 12.7 mm choke. The GOR was 190, the oil density was 0.829 g/cm3, and the gas gravity was 0.744 (air = 1). The CO2 content was 1.5 percent and the H2S content was 0.2 ppm. The down hole temperature measured in the test was 109.0 deg C.
    DST 2 in the interval 2801.5 - 2819.5 m produced 575 Sm3 oil and 105800 Sm3 gas /day through a 12.7 mm choke. The GOR was 184, the oil density was 0.825 g/cm3, and the gas gravity was 0.0.685 (air = 1). The CO2 content was 1.5 percent and the H2S content was 1.5 ppm. The down hole temperature measured in the test was 111.2 deg 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]
    780.00
    3320.00

  • 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
    2673.0
    2686.9
    [m ]
    2
    2701.0
    2718.9
    [m ]
    3
    2723.0
    2739.6
    [m ]
    4
    2775.0
    2787.1
    [m ]
    5
    2791.5
    2803.2
    [m ]
    6
    2804.5
    2823.5
    [m ]
    7
    2823.5
    2841.1
    [m ]
    8
    2841.5
    2869.4
    [m ]
    9
    2869.5
    2869.8
    [m ]
    10
    2879.0
    2896.0
    [m ]
    11
    2896.0
    2913.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    171.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2673-2679m
    Core photo at depth: 2679-2685m
    Core photo at depth: 2685-2686m
    Core photo at depth: 2701-2707m
    Core photo at depth: 2707-2713m
    2673-2679m
    2679-2685m
    2685-2686m
    2701-2707m
    2707-2713m
    Core photo at depth: 2713-2718m
    Core photo at depth: 2723-2729m
    Core photo at depth: 2729-2735m
    Core photo at depth: 2735-2739m
    Core photo at depth: 2775-2781m
    2713-2718m
    2723-2729m
    2729-2735m
    2735-2739m
    2775-2781m
    Core photo at depth: 2781-2787m
    Core photo at depth: 2787-2787m
    Core photo at depth: 2791-2797m
    Core photo at depth: 2797-2803m
    Core photo at depth: 2804-2810m
    2781-2787m
    2787-2787m
    2791-2797m
    2797-2803m
    2804-2810m
    Core photo at depth: 2810-2816m
    Core photo at depth: 2816-2822m
    Core photo at depth: 2822-2823m
    Core photo at depth: 2823-2829m
    Core photo at depth: 2829-2835m
    2810-2816m
    2816-2822m
    2822-2823m
    2823-2829m
    2829-2835m
    Core photo at depth: 2835-2841m
    Core photo at depth: 2841-2842m
    Core photo at depth: 2842-2847m
    Core photo at depth: 2847-2853m
    Core photo at depth: 2853-2859m
    2835-2841m
    2841-2842m
    2842-2847m
    2847-2853m
    2853-2859m
    Core photo at depth: 2859-2865m
    Core photo at depth: 2865-2869m
    Core photo at depth: 2869-2870m
    Core photo at depth: 2879-2885m
    Core photo at depth: 2885-2891m
    2859-2865m
    2865-2869m
    2869-2870m
    2879-2885m
    2885-2891m
    Core photo at depth: 2891-2896m
    Core photo at depth: 2896-2902m
    Core photo at depth: 2902-2908m
    Core photo at depth: 2908-2913m
    Core photo at depth:  
    2891-2896m
    2896-2902m
    2902-2908m
    2908-2913m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2675.9
    [m]
    C
    OD
    2676.1
    [m]
    C
    OD

  • 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
    2869.00
    2878.00
    06.01.1987 - 00:00
    YES
    DST
    DST2
    2801.50
    2819.50
    OIL
    12.01.1987 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.33
    pdf
    2.41
    pdf
    13.21
    pdf
    1.28

  • 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
    9.41
    pdf
    9.10

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2870
    2879
    12.7
    2.0
    2802
    2820
    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
    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
    125
    24000
    0.829
    0.744
    190
    2.0
    575
    106000
    0.825
    0.685
    184

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    435
    1501
    CBL VDL
    1300
    3248
    CET GR
    2491
    3184
    CST GR
    1708
    2550
    CST GR
    2552
    3315
    CST GR
    2553
    3315
    DIL LSS GR SP
    1501
    2548
    DITE LSS MSFL GR SP
    2533
    3320
    DLL SP
    2600
    3000
    LDL CNL NGT
    2533
    3321
    MWD - GR RES DIR
    361
    2520
    MWD - GR RES DIR
    3025
    3305
    RFT GR
    2698
    2884
    RFT GR
    2701
    2925
    RFT GR
    2816
    3093
    SHDT GR
    1501
    2550
    SHDT GR
    2533
    3320
    VSP
    1080
    3260

  • 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
    445.0
    36
    446.0
    0.00
    LOT
    INTERM.
    13 3/8
    757.0
    17 1/2
    1517.0
    1.76
    LOT
    INTERM.
    9 5/8
    2535.0
    12 1/4
    2550.0
    1.87
    LOT
    LINER
    7
    3316.0
    8 1/2
    3320.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    382
    1.05
    99.0
    99.0
    WATERBASED
    20.11.1986
    406
    1.05
    99.0
    99.0
    WATERBASED
    21.11.1986
    446
    1.05
    WATERBASED
    24.11.1986
    650
    0.00
    WATERBASED
    19.01.1987
    780
    1.05
    WATERBASED
    24.11.1986
    780
    0.00
    18.0
    10.0
    WATERBASED
    26.11.1986
    1000
    1.47
    11.0
    12.0
    WATER BASED
    22.03.1990
    1160
    1.20
    24.0
    18.0
    WATERBASED
    25.11.1986
    1517
    1.30
    20.0
    13.0
    WATERBASED
    27.11.1986
    1517
    0.00
    20.0
    15.0
    WATERBASED
    30.11.1986
    1517
    0.00
    22.0
    9.0
    WATERBASED
    30.11.1986
    1839
    1.60
    30.0
    15.0
    WATERBASED
    30.11.1986
    2016
    1.60
    33.0
    10.0
    WATER BASED
    02.12.1986
    2190
    1.60
    28.0
    8.0
    WATER BASED
    02.12.1986
    2230
    1.60
    28.0
    8.0
    WATERBASED
    03.12.1986
    2310
    1.60
    30.0
    10.0
    WATERBASED
    04.12.1986
    2372
    1.48
    19.0
    11.0
    WATER BASED
    22.03.1990
    2409
    1.60
    25.0
    7.0
    WATERBASED
    06.12.1986
    2464
    1.47
    19.0
    10.0
    WATER BASED
    22.03.1990
    2513
    1.60
    27.0
    9.0
    WATERBASED
    06.12.1986
    2535
    1.49
    20.0
    4.0
    WATERBASED
    10.12.1986
    2535
    0.00
    21.0
    5.0
    WATERBASED
    11.12.1986
    2550
    1.60
    25.0
    8.0
    WATERBASED
    06.12.1986
    2550
    0.00
    29.0
    9.0
    WATERBASED
    09.12.1986
    2550
    0.00
    29.0
    9.0
    WATERBASED
    08.12.1986
    2553
    1.48
    17.0
    8.0
    WATERBASED
    14.12.1986
    2582
    1.48
    20.0
    8.0
    WATERBASED
    14.12.1986
    2651
    1.48
    24.0
    8.0
    WATERBASED
    14.12.1986
    2680
    1.48
    21.0
    8.0
    WATERBASED
    15.12.1986
    2701
    1.48
    21.0
    8.0
    WATERBASED
    16.12.1986
    2731
    1.48
    19.0
    7.0
    WATERBASED
    17.12.1986
    2775
    1.48
    22.0
    8.0
    WATERBASED
    18.12.1986
    2794
    1.48
    11.0
    7.0
    WATER BASED
    22.03.1990
    2796
    1.48
    20.0
    6.0
    WATERBASED
    19.01.1987
    2805
    1.48
    23.0
    8.0
    WATERBASED
    20.12.1986
    2819
    1.48
    24.0
    8.0
    WATERBASED
    14.01.1987
    2819
    0.00
    20.0
    6.0
    WATERBASED
    19.01.1987
    2819
    0.00
    20.0
    6.0
    WATERBASED
    15.01.1987
    2819
    0.00
    20.0
    6.0
    WATERBASED
    16.01.1987
    2842
    1.48
    22.0
    8.0
    WATERBASED
    20.12.1986
    2859
    1.48
    23.0
    8.0
    WATERBASED
    13.01.1987
    2861
    1.48
    19.0
    7.0
    WATERBASED
    12.01.1987
    2879
    1.48
    23.0
    7.0
    WATERBASED
    20.12.1986
    2915
    1.48
    24.0
    8.0
    WATERBASED
    23.12.1986
    2970
    1.48
    18.0
    11.0
    WATER BASED
    22.03.1990
    2994
    1.48
    25.0
    9.0
    WATERBASED
    29.12.1986
    3028
    1.48
    23.0
    8.0
    WATERBASED
    30.12.1986
    3039
    1.48
    23.0
    8.0
    WATERBASED
    30.12.1986
    3078
    1.48
    23.0
    8.0
    WATERBASED
    30.12.1986
    3182
    1.48
    24.0
    9.0
    WATERBASED
    30.12.1986
    3265
    1.48
    22.0
    7.0
    WATERBASED
    06.01.1987
    3265
    0.00
    22.0
    7.0
    WATERBASED
    06.01.1987
    3265
    0.00
    22.0
    7.0
    WATERBASED
    07.01.1987
    3265
    0.00
    21.0
    5.0
    WATERBASED
    09.01.1987
    3265
    0.00
    23.0
    6.0
    WATERBASED
    12.01.1987
    3265
    0.00
    18.0
    6.0
    WATERBASED
    12.01.1987
    3265
    1.48
    17.0
    12.0
    WATER BASED
    22.03.1990
    3265
    1.48
    17.0
    16.0
    WATER BASED
    22.03.1990
    3265
    1.48
    18.0
    15.0
    WATER BASED
    23.03.1990
    3265
    1.48
    17.0
    14.0
    WATER BASED
    26.03.1990
    3265
    1.47
    17.0
    14.0
    WATER BASED
    26.03.1990
    3265
    1.47
    14.0
    13.0
    WATER BASED
    27.03.1990
    3265
    1.47
    14.0
    12.0
    WATER BASED
    28.03.1990
    3265
    1.47
    15.0
    14.0
    WATER BASED
    02.04.1990
    3265
    1.48
    15.0
    13.0
    WATER BASED
    02.04.1990
    3265
    1.48
    15.0
    13.0
    WATER BASED
    02.04.1990
    3265
    1.48
    15.0
    13.0
    WATER BASED
    04.04.1990
    3265
    1.48
    15.0
    13.0
    WATER BASED
    04.04.1990
    3265
    1.47
    15.0
    12.0
    WATER BASED
    06.04.1990
    3265
    1.48
    15.0
    13.0
    WATER BASED
    09.04.1990
    3265
    1.48
    15.0
    13.0
    WATER BASED
    09.04.1990
    3265
    1.48
    15.0
    13.0
    WATER BASED
    10.04.1990
    3265
    1.48
    15.0
    13.0
    WATER BASED
    11.04.1990
    3265
    1.48
    15.0
    13.0
    WATER BASED
    18.04.1990
    3265
    1.48
    15.0
    12.0
    WATER BASED
    18.04.1990
    3265
    1.48
    14.0
    9.0
    WATER BASED
    18.04.1990
    3265
    1.47
    15.0
    14.0
    WATER BASED
    18.04.1990
    3265
    1.02
    1.0
    1.0
    WATER BASED
    18.04.1990
    3265
    1.47
    15.0
    14.0
    WATER BASED
    24.04.1990
    3265
    1.47
    15.0
    14.0
    WATER BASED
    24.04.1990
    3265
    1.47
    15.0
    14.0
    WATER BASED
    24.04.1990
    3265
    1.47
    15.0
    14.0
    WATER BASED
    24.04.1990
    3265
    1.47
    13.0
    13.0
    WATER BASED
    27.04.1990
    3265
    1.45
    13.0
    12.0
    WATER BASED
    27.04.1990
    3265
    1.48
    12.0
    12.0
    WATER BASED
    30.03.1990
    3265
    1.48
    15.0
    17.0
    WATER BASED
    30.03.1990
    3265
    1.48
    15.0
    13.0
    WATER BASED
    05.04.1990
    3265
    1.48
    15.0
    13.0
    WATER BASED
    09.04.1990
    3265
    1.47
    15.0
    14.0
    WATER BASED
    18.04.1990
    3265
    1.47
    15.0
    14.0
    WATER BASED
    25.04.1990
    3265
    0.00
    22.0
    7.0
    WATERBASED
    09.01.1987
    3266
    1.49
    25.0
    6.0
    WATERBASED
    05.01.1987
    3276
    1.48
    24.0
    10.0
    WATERBASED
    30.12.1986
    3320
    0.00
    24.0
    6.0
    WATERBASED
    05.01.1987
    3320
    1.48
    23.0
    8.0
    WATERBASED
    30.12.1986
    3320
    0.00
    23.0
    8.0
    WATERBASED
    02.01.1987
    3320
    0.00
    24.0
    8.0
    WATERBASED
    02.01.1987

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2701.60
    [m ]
    2710.90
    [m ]
    2806.90
    [m ]
    2811.60
    [m ]
    2842.60
    [m ]
    2853.60
    [m ]
    2868.30
    [m ]
    2895.40
    [m ]
    2911.90
    [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
    0.28