Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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29/3-1

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    29/3-1
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

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

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

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

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    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.
    29/3-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SL: NOD5 - 85 - 04 SP. 245
    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.
    Total Norge AS
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    514-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.
    119
    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,
    20.05.1986
    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.
    15.09.1986
    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.
    15.09.1988
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    17.12.2003
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

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

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    OIL/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.
    YES
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    MIDDLE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    NESS FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    131.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4427.0
    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).
    4419.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    18.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    150
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 57' 50.24'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 56' 13.25'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6759399.56
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    442441.23
    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.
    904

  • Wellbore history
    General
    Well 29/3-1 was drilled in an area adjacent to several major hydrocarbon discoveries close to the UK-Norway median line. The structure is located in the highest part of a westerly tilted fault panel and the closure is provided by fault to the North East and South and by structural dips westward.
    The objectives of the well were to test hydrocarbon potential of the Middle Jurassic Brent sandstones; and to test the reservoir potential of the Dunlin sands.
    Operations and results
    Wildcat well 29/3-1 was spudded 20 may 1986 by Dolphin Services A/S semi-submersible installation Byford Dolphin and completed 15 September 1986 at a depth of 4427 m in the Early Jurassic Statfjord Formation. The 17 1/2" hole (756 m to 2252 m) was drilled with KCL/polymer fluid. Well section below 13 3/8" casing point (2252 m) was drilled oil based with Safemul Invert Emulsion mud (80 % base oil). Drilling was delayed due to a destroyed guide block, after that drilling proceeded without significant problems. The Tarbert Formation was water bearing with residual hydrocarbons and minor amounts of gas in the top section. The lower Ness Formation contained a 150 m hydrocarbon column. The Dunlin Group was water bearing. The Statfjord Formation was found tight and water bearing. Two cores were cut in the Brent sandstones in the interval 3525 m to 3561 m. Five RFT samples were taken in the Brent Group: 3821.5 m (Ness: oil and water), 3719 m (Ness: oil and gas), 3697.8 m (Ness: oil and gas), 3556.4 m (Tarbert: water and filtrate), and 3530 m (Tarbert: gas and water). All samples showed unusually high oil filtrate recovery due to a very deep invasion by the oil base mud.
    The well was plugged and abandoned as a gas and oil discovery.
    Testing
    Four drillstem tests were performed in the Brent Group.
    DST 1B was performed in three zones in the Ness Formation over the interval 3802 m to 3822 m. In this test no flow of reservoir fluid reached surface in 22 hours however, oil (specific gravity: 0.88 g/cm3) and gas (specific gravity (air=l): 0.69) was recovered during reverse circulation.
    DST 2B was performed in three zones in the Ness Formation over the interval 3682 m to 3725 m. In this test oil rates varied from 665 Sm3 to 433 Sm3 pr day, gas rates varied between 395000 Sm3 to 535000 Sm3 pr day. GOR varied correspondingly between 595 Sm3/Sm3 to 1235 Sm3/Sm3, indicating gas coning from a gas-cap, with the presence of the gas-oil contact near the well. Oil density was 0.87 g/cm3 and gas gravity was 0.68 (air = 1).
    DST 2C was performed in two zones in the Ness Formation over the interval 3682 m to 3699 m. The test flowed 238.5 Sm3 oil and 438960 Sm3 gas pr day with a GOR of 1840 Sm3/Sm3. Oil density was 0.85 and gas gravity was 0.72.
    DST 3 was performed in the interval 3522 m to 3530 m in the Tarbert Formation. It produced only Formation water with a little gas.

  • 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]
    210.00
    4426.00

  • 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
    3525.0
    3542.9
    [m ]
    2
    3543.2
    3560.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    34.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3525-3542m
    Core photo at depth: 3525-3536m
    Core photo at depth: 3525-3542m
    Core photo at depth: 3543-3546m
    Core photo at depth: 3549-3554m
    3525-3542m
    3525-3536m
    3525-3542m
    3543-3546m
    3549-3554m
    Core photo at depth: 3555-3560m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3555-3560m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1450.0
    [m]
    DC
    GEOCH
    1480.0
    [m]
    DC
    GEOCH
    1510.0
    [m]
    DC
    GEOCH
    1540.0
    [m]
    DC
    GEOCH
    1570.0
    [m]
    DC
    GEOCH
    1600.0
    [m]
    DC
    GEOCH
    1630.0
    [m]
    DC
    GEOCH
    1660.0
    [m]
    DC
    GEOCH
    1690.0
    [m]
    DC
    GEOCH
    1720.0
    [m]
    DC
    GEOCH
    1750.0
    [m]
    DC
    GEOCH
    1780.0
    [m]
    DC
    GEOCH
    1810.0
    [m]
    DC
    GEOCH
    1840.0
    [m]
    DC
    GEOCH
    1870.0
    [m]
    DC
    GEOCH
    1900.0
    [m]
    DC
    GEOCH
    1930.0
    [m]
    DC
    GEOCH
    1960.0
    [m]
    DC
    GEOCH
    1990.0
    [m]
    DC
    GEOCH
    2020.0
    [m]
    DC
    GEOCH
    2050.0
    [m]
    DC
    GEOCH
    2080.0
    [m]
    DC
    GEOCH

  • 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
    DST1B
    3822.00
    3802.00
    24.08.1986 - 00:00
    YES
    DST
    DST2B
    3725.00
    3682.00
    02.09.1986 - 00:00
    YES
    DST
    DST2C
    3699.00
    3682.00
    05.09.1986 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.48

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.89
    pdf
    1.56

  • 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
    18.13

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3802
    3822
    7.9
    2.0
    3682
    3725
    12.7
    2.1
    3682
    3699
    12.7
    3.0
    3522
    3530
    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
    36.000
    130
    2.0
    54.000
    30.000
    50.000
    124
    2.1
    54.000
    21.000
    37.000
    129
    3.0
    48.000
    1.000
    34.000
    119
    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
    0.878
    0.690
    2.0
    440
    534000
    0.868
    0.680
    1212
    2.1
    236
    438000
    0.845
    0.720
    1858
    3.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGL GR
    756
    2250
    CBL VDL GR
    1246
    2248
    CBL VDL GR
    1900
    3468
    CORR DST-2
    3495
    3615
    CORR DST-3
    3390
    3475
    CST
    3475
    4385
    DELTA-T
    3468
    3847
    DIPMETER
    3470
    4428
    DIS BHC GR
    156
    758
    DIS BHC GR
    756
    900
    DIS BHC GR
    756
    2250
    DIS BHC GR
    2251
    3485
    DIS BHC GR
    3468
    3613
    DIS GR
    2251
    3427
    DITE SDTA GR
    4432
    3550
    ENERJET-220
    0
    220
    EPL PCD
    3468
    4433
    JB BRIDGE PLUG
    3200
    3450
    JB BRIDGR PLUG
    3440
    3450
    JB PACKER DST-2C
    3645
    3708
    JB PLUG DST-2
    3716
    3747
    JB PLUG DST-3
    3548
    3599
    LDL CNL GR
    2251
    3487
    LDL CNL GR
    3468
    4433
    MWD
    208
    4427
    NGS
    4433
    3468
    RFT GR
    3526
    3543
    RFT HP
    3530
    3861
    RFT HP
    3530
    3697
    RFT HP
    3553
    3821
    RFT HP
    3556
    3610
    RFT HP
    3719
    4050
    VSP
    800
    2240
    VSP
    2100
    4430

  • 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
    204.0
    36
    208.0
    1.13
    LOT
    SURF.COND.
    20
    756.0
    26
    770.0
    1.49
    LOT
    INTERM.
    13 3/8
    2252.0
    17 1/2
    2265.0
    1.87
    LOT
    INTERM.
    9 5/8
    3468.0
    12 1/4
    3484.0
    2.06
    LOT
    LINER
    7
    4427.0
    8 1/2
    4427.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    204
    1.05
    10.0
    20.0
    WATER BASED
    23.05.1986
    204
    1.05
    10.0
    WATER BASED
    20.05.1986
    208
    1.05
    10.0
    20.0
    WATER BASED
    21.05.1986
    295
    1.12
    17.0
    26.0
    WATER BASED
    23.05.1986
    760
    1.13
    17.0
    26.0
    WATER BASED
    23.05.1986
    770
    1.13
    17.0
    26.0
    WATER BASED
    23.05.1986
    770
    1.15
    15.0
    10.0
    WATER BASED
    08.06.1986
    770
    1.15
    17.0
    10.8
    WATER BASED
    08.06.1986
    770
    1.15
    17.0
    11.3
    WATER BASED
    10.06.1986
    770
    1.05
    10.0
    10.0
    WATER BASED
    11.06.1986
    770
    1.10
    17.0
    7.0
    WATER BASED
    15.06.1986
    770
    1.15
    17.0
    11.3
    WATER BASED
    09.06.1986
    931
    1.10
    16.0
    6.7
    WATER BASED
    15.06.1986
    1471
    1.14
    18.0
    10.5
    WATER BASED
    15.06.1986
    1583
    1.14
    18.0
    10.5
    WATER BASED
    15.06.1986
    1782
    1.20
    22.0
    11.0
    WATER BASED
    16.06.1986
    1944
    1.20
    20.0
    10.5
    WATER BASED
    17.06.1986
    2035
    1.22
    19.0
    9.6
    WATER BASED
    18.06.1986
    2169
    1.21
    26.0
    11.5
    WATER BASED
    19.06.1986
    2252
    1.30
    21.0
    9.0
    WATER BASED
    29.06.1986
    2252
    1.30
    21.0
    9.0
    WATER BASED
    26.06.1986
    2265
    1.23
    17.0
    8.0
    WATER BASED
    22.06.1986
    2265
    1.30
    21.0
    9.0
    WATER BASED
    24.06.1986
    2265
    1.20
    26.0
    12.4
    WATER BASED
    22.06.1986
    2265
    1.25
    19.0
    9.0
    WATER BASED
    23.06.1986
    2265
    1.30
    2.1
    9.0
    WATER BASED
    25.06.1986
    2280
    1.30
    21.0
    9.0
    WATER BASED
    29.06.1986
    2500
    1.35
    17.0
    6.5
    OIL BASED
    29.06.1986
    2795
    1.35
    17.0
    13.0
    OIL BASED
    30.06.1986
    3182
    1.47
    21.0
    7.0
    OIL BASED
    01.07.1986
    3329
    1.50
    19.0
    8.0
    OIL BASED
    02.07.1986
    3395
    1.50
    21.0
    7.5
    OIL BASED
    03.07.1986
    3426
    1.50
    20.0
    7.0
    OIL BASED
    06.07.1986
    3427
    1.58
    24.0
    9.1
    OIL BASED
    04.08.1986
    3468
    1.50
    20.0
    9.0
    OIL BASED
    09.07.1986
    3468
    1.50
    20.0
    9.5
    OIL BASED
    10.07.1986
    3474
    1.50
    22.0
    9.0
    OIL BASED
    06.07.1986
    3484
    1.50
    21.0
    8.5
    OIL BASED
    06.07.1986
    3484
    1.50
    20.0
    10.0
    OIL BASED
    08.07.1986
    3484
    1.50
    20.0
    10.0
    OIL BASED
    07.07.1986
    3507
    1.50
    20.0
    9.5
    OIL BASED
    14.07.1986
    3522
    1.60
    14.0
    13.0
    OIL BASED
    09.09.1986
    3522
    1.60
    14.0
    13.0
    OIL BASED
    11.09.1986
    3525
    1.51
    19.0
    9.0
    OIL BASED
    14.07.1986
    3543
    1.51
    19.0
    9.0
    OIL BASED
    14.07.1986
    3561
    1.46
    16.0
    9.0
    OIL BASED
    14.07.1986
    3600
    1.59
    6.0
    27.0
    OIL BASED
    09.09.1986
    3600
    1.60
    14.0
    13.0
    OIL BASED
    09.09.1986
    3613
    1.46
    20.0
    7.0
    OIL BASED
    15.07.1986
    3613
    1.46
    18.0
    8.0
    OIL BASED
    16.07.1986
    3672
    1.46
    19.0
    8.0
    OIL BASED
    17.07.1986
    3685
    1.55
    17.0
    7.7
    OIL BASED
    21.07.1986
    3715
    1.55
    17.0
    7.7
    OIL BASED
    21.07.1986
    3728
    1.56
    18.0
    8.6
    OIL BASED
    21.07.1986
    3750
    1.59
    32.0
    8.0
    OIL BASED
    26.08.1986
    3794
    1.56
    19.0
    9.0
    OIL BASED
    21.07.1986
    3883
    1.56
    18.0
    7.7
    OIL BASED
    22.07.1986
    3900
    1.59
    22.0
    8.0
    OIL BASED
    11.08.1986
    3916
    1.59
    22.0
    8.0
    OIL BASED
    11.08.1986
    3916
    1.59
    22.0
    8.0
    OIL BASED
    12.08.1986
    3917
    1.59
    22.0
    8.0
    OIL BASED
    11.08.1986
    3928
    1.56
    18.0
    8.6
    OIL BASED
    23.07.1986
    3928
    1.56
    19.0
    8.6
    OIL BASED
    24.07.1986
    3999
    1.56
    24.0
    10.5
    OIL BASED
    28.07.1986
    4054
    1.56
    24.0
    9.1
    OIL BASED
    28.07.1986
    4172
    1.56
    24.0
    9.1
    OIL BASED
    28.07.1986
    4298
    1.58
    24.0
    10.5
    OIL BASED
    30.07.1986
    4384
    1.58
    24.0
    9.6
    OIL BASED
    30.07.1986
    4385
    1.58
    24.0
    9.6
    OIL BASED
    31.07.1986
    4385
    1.58
    24.0
    9.6
    OIL BASED
    01.08.1986
    4427
    1.58
    24.0
    9.1
    OIL BASED
    04.08.1986
    4427
    1.58
    24.0
    9.1
    OIL BASED
    05.08.1986
    4427
    1.58
    24.0
    8.1
    OIL BASED
    04.08.1986
    4427
    1.59
    22.0
    7.6
    OIL BASED
    06.08.1986
    4427
    1.59
    22.0
    7.6
    OIL BASED
    07.08.1986
    4427
    1.59
    22.0
    7.6
    OIL BASED
    08.08.1986

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3546.25
    [m ]
    3535.80
    [m ]
    3536.00
    [m ]
    3532.60
    [m ]
    3525.40
    [m ]
    3527.60
    [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