Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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31.10.2024 - 01:27
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35/11-2

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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.
    35/11-2
    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
    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.
    35/11-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NM84 - 208 SP. 520
    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.
    Mobil Exploration Norway INC
    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.
    553-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.
    138
    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,
    20.07.1987
    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.
    04.12.1987
    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.
    04.12.1989
    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.
    25.04.2005
    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.
    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.
    BRENT GP
    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.
    372.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4025.0
    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).
    4024.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    153
    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.
    61° 10' 26.42'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 27' 31.36'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6782416.83
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    524675.04
    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.
    893

  • Wellbore history
    General
    Block 35/11 is situated at the boundary between the Horda Platform and the Viking Graben just north of the Troll Field and south of block 35/8 where two gas/condensate discoveries had been made. The work obligation for Block 35/11 included three exploration wells to be drilled to 4000 metres or to Triassic sediments, one of which must test an Early Cretaceous stratigraphic play. The first of these wells, 35/11-1, was drilled in 1984 to a depth of 3361 m in rocks of Triassic age. The primary objective of that well was to assess the hydrocarbon potential of the Middle to Upper Jurassic sands in the "A" structure. No hydrocarbons were present in any of the objectives although good quality Brent sands were encountered. The second well to be drilled on the block was 35/11-2. It was designed primarily to test an Early Cretaceous stratigraphic play, interpreted seismically as a fan development with a 130 km3 closure, and reservoir thickness of 270 m. A secondary objective was the "B" structure at Brent level.
    Operations and results
    Wildcat well 35/11-2 was spudded with the semi-submersible rig Treasure Scout on 20 July 1987 and drilled to TD at 4025 m in Early Jurassic rocks. The hole was drilled to setting depth for 20" casing without a riser. MWD was used, but the resistivity unit was destroyed after few meters. Conventional logs did not get past 760 m, and while attempting this; there was an intrusion of formation fluid into the hole. There was no sign of shallow gas, and heavier mud was used. The hole was opened to 26" without logging below 760 m. The reason for the problems around 760 m was probably washed-out zones. When preparing the setting of 20"casing, fluid was again flowing into the hole, and the mud weight was increased. Further drilling went without significant problems. The well was drilled with spud mud down to 1026 m, with seawater and lignosulphonate from 1026 m to 2195 m, and with a seawater/low solids polymer from 2195 m to TD.
    The well penetrated the Early Cretaceous at 2682 m (prognosed at 2713 m) and intersected a 225 m thick, predominantly argillaceous/marly sequence. No reservoir rocks were penetrated. At 3011 m Intra Heather Formation sandstone was encountered, and at 3370 m the Brent Group was penetrated (prognosed at 3298 m). The Brent section was 231 m thick with reservoir quality sandstones in the Tarbert, Ness, Etive, and Oseberg Formations. It contained a 175 m gross hydrocarbon column, but the net/gross ratio is low. The logs and RFT pressure data showed a gas/water contact around 3545 m (3522 m SS) in the Oseberg Formation. Oil shows were observed in the Late Jurassic Intra Heather sandstone and throughout the Middle Jurassic Brent Group sandstones. Patchy shows persisted through the Dunlin Group and the Statfjord Formation to total depth. Organic geochemical analyses showed good source rock potential in the Draupne and the Heather Formations, the first of these being the best and more oil prone. The penetrated source intervals were immature to marginally mature, and certainly less mature than the sampled petroleum. Analysis of the DST oils indicated a common source, and the oils increased in maturity with depth.
    Eight cores were cut in the Late and Middle Jurassic reservoirs (total 129 m). Core recovery was 124.9 m (97%). Four RFT fluid samples were taken. Sample RFT 1 taken at 3040.99 m in the Intra Heather Formation sandstone filled very slowly and recovered gas and mud filtrate with a light oil film. Sample RFT 2 at 3077 m in the Tarbert Formation recovered gas and mud filtrate. Sample RFT 3 at 3481.05 m in the Etive Formation recovered gas and condensate. Sample RFT 4 at3524.98 m in the Oseberg Formation recovered gas and condensate.
    The well was plugged and abandoned on 4 December 1987 as a gas and condensate discovery.
    Testing
    Five drill stem tests, including one in the water leg, were undertaken. The Intra Heather sandstone was tight, with a low net/gross, and was not tested.
    DST 1, the water test in the lower Oseberg Formation, produced 315 m3 water/day through a 28/64? choke in the main flow. The reservoir temperature was 136 °C.
    DST 2B in the upper Oseberg Formation produced at maximum 280 Sm3 condensate and 369000 gas /day through a 48/64? choke. The GOR was 1319 Sm3/Sm3. The reservoir temperature was 133.3 °C.
    DST 3 in the Etive Formation produced at maximum 510 Sm3 condensate and 531000 gas /day through a 40/64? choke. The GOR was 1041Sm3/Sm3. The reservoir temperature was 133.3 °C.
    DST 4 in the Ness Formation produced at maximum 425 Sm3 condensate and 402400 Sm3 gas /day through a 44/64? choke. The GOR was 946 Sm3/Sm3. The reservoir temperature was 135 °C.
    DST 5 in the Tarbert Formation produced 415 Sm3 condensate and 177400 Sm3 gas /day through a 32/64? choke in the main flow. The GOR was 427 Sm3/Sm3. The reservoir temperature was 130 °C. This test indicated that there is a thin Tarbert Formation on the top without connection to the rest of the reservoir because the GOR is less than half of the GOR in the other tests.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    1030.00
    4025.00

  • Cores at the Norwegian Offshore Directorate
    Cores at the Norwegian Offshore Directorate
    Core sample number
    Core sample - top depth
    Core sample - bottom depth
    Core sample depth - uom
    2
    3042.0
    3045.2
    [m ]
    3
    3369.0
    3391.6
    [m ]
    4
    3392.9
    3413.7
    [m ]
    5
    3414.0
    3428.9
    [m ]
    6
    3452.0
    3462.5
    [m ]
    7
    3463.0
    3489.3
    [m ]
    8
    3490.0
    3516.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    124.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1040.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    2015.0
    [m]
    DC
    RRI
    2175.0
    [m]
    DC
    RRI
    2332.0
    [m]
    DC
    RRI
    2335.0
    [m]
    DC
    RRI
    2495.0
    [m]
    DC
    RRI
    2605.0
    [m]
    DC
    RRI
    2694.0
    [m]
    DC
    RRI
    2720.5
    [m]
    SWC
    RRI
    2745.0
    [m]
    DC
    RRI
    2760.0
    [m]
    DC
    RRI
    2772.0
    [m]
    DC
    RRI
    2808.0
    [m]
    DC
    RRI
    2835.0
    [m]
    DC
    RRI
    2841.0
    [m]
    DC
    RRI
    2865.0
    [m]
    DC
    RRI
    2940.0
    [m]
    DC
    RRI
    2950.0
    [m]
    DC
    RRI
    2970.0
    [m]
    DC
    RRI
    2991.0
    [m]
    DC
    RRI
    3012.0
    [m]
    DC
    RRI
    3033.0
    [m]
    DC
    RRI
    3042.3
    [m]
    C
    RRI
    3042.9
    [m]
    C
    RRI
    3044.2
    [m]
    C
    RRI
    3044.8
    [m]
    C
    RRI
    3045.0
    [m]
    DC
    RRI
    3045.2
    [m]
    C
    RRI
    3135.0
    [m]
    DC
    RRI
    3174.0
    [m]
    DC
    RRI
    3246.0
    [m]
    DC
    RRI
    3300.0
    [m]
    DC
    RRI
    3354.0
    [m]
    DC
    RRI
    3371.4
    [m]
    C
    GEOSTRAT
    3375.0
    [m]
    C
    RRI
    3376.6
    [m]
    C
    GEOSTRAT
    3382.3
    [m]
    C
    GEOSTR
    3383.0
    [m]
    C
    RRI
    3393.5
    [m]
    C
    GEOSTRAT
    3397.0
    [m]
    C
    RRI
    3400.2
    [m]
    C
    GEOSTRAT
    3411.0
    [m]
    C
    RRI
    3411.6
    [m]
    C
    GEOSTR
    3412.0
    [m]
    C
    RRI
    3421.7
    [m]
    C
    RRI
    3422.0
    [m]
    C
    RRI
    3456.8
    [m]
    C
    GEOSTRAT
    3462.1
    [m]
    C
    GEOSTR
    3462.3
    [m]
    C
    RRI
    3468.7
    [m]
    C
    GEOSTRAT
    3474.0
    [m]
    C
    RRI
    3478.9
    [m]
    C
    GEOSTR
    3480.2
    [m]
    C
    RRI
    3492.9
    [m]
    C
    GEOSTRAT
    3505.3
    [m]
    C
    GEOSTR
    3511.0
    [m]
    C
    RRI
    3515.8
    [m]
    C
    GEOSTRAT
    3525.0
    [m]
    C
    RRI
    3612.0
    [m]
    DC
    RRI
    3630.0
    [m]
    DC
    RRI
    3648.0
    [m]
    DC
    RRI
    3672.0
    [m]
    DC
    RRI
    3690.0
    [m]
    DC
    RRI
    3762.0
    [m]
    DC
    RRI
    3777.0
    [m]
    C
    RRI
    3822.0
    [m]
    DC
    RRI
    3846.0
    [m]
    DC
    RRI
    3870.0
    [m]
    DC
    RRI
    3900.0
    [m]
    DC
    RRI
    3942.0
    [m]
    DC
    RRI
    3960.0
    [m]
    DC
    RRI
    3978.0
    [m]
    DC
    RRI

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    DST2
    3524.00
    3542.00
    03.11.1987 - 00:00
    YES
    DST
    3524.00
    3542.00
    09.11.1987 - 00:00
    YES
    DST
    DST2B
    0.00
    0.00
    09.11.1987 - 00:00
    YES
    DST
    DST3
    3477.00
    3486.50
    12.11.1987 - 00:00
    YES
    DST
    DST4
    3370.00
    3378.00
    14.11.1987 - 00:00
    YES
    DST
    DST4
    0.00
    0.00
    14.11.1987 - 02:00
    YES
    DST
    DST4
    3427.00
    3432.00
    14.11.1987 - 00:00
    YES
    DST
    3374.00
    3378.00
    19.11.1987 - 00:00
    YES
    DST
    DST 5
    3378.00
    3374.00
    19.11.1987 - 00:00
    YES
    DST
    DST5A
    3374.00
    3378.00
    YES

  • 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
    1.37
    pdf
    4.51
    pdf
    1.09

  • 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
    46.01

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3551
    3559
    10.7
    2.0
    3524
    3542
    18.3
    3.0
    3477
    3487
    15.9
    4.0
    3427
    3432
    17.4
    5.0
    3374
    3378
    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
    50.000
    136
    2.0
    45.000
    49.000
    133
    3.0
    42.000
    49.000
    133
    4.0
    31.000
    48.000
    135
    5.0
    29.000
    48.000
    130
    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
    5
    2.0
    280
    36900
    0.811
    0.719
    1319
    3.0
    510
    531000
    0.820
    0.739
    1041
    4.0
    425
    402400
    0.822
    0.740
    946
    5.0
    415
    177400
    0.828
    0.780
    427

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    857
    2184
    CBL VDL GR
    2163
    3348
    CBL VDL GR
    3356
    3972
    CET GR
    3262
    3596
    CST
    0
    0
    DIL BHC GR
    547
    759
    DIL BHC GR
    1002
    2188
    DIL LSS GR
    390
    759
    DIL LSS GR
    2185
    3372
    DIL SDT GR
    3350
    4028
    DLL MSFL GR
    2185
    3372
    DLL MSFL GR
    3350
    4026
    LDL CNL GR
    725
    2188
    LDL CNL GR
    2185
    3373
    LDL CNL NGS
    3350
    4030
    MWD - GR RES DIR
    372
    4025
    MWD - GR RLL
    3378
    3517
    NGS
    3350
    4030
    RFT
    2945
    3042
    RFT
    2995
    3373
    RFT
    3377
    3963
    SHDT
    2185
    3373
    SHDT
    3350
    4029
    VELOCITY
    1430
    4030

  • 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
    546.8
    36
    1026.0
    0.00
    LOT
    SURF.COND.
    20
    1004.0
    26
    1026.0
    1.39
    LOT
    INTERM.
    13 3/8
    2184.6
    17 1/2
    2195.0
    1.62
    LOT
    INTERM.
    9 3/5
    3348.8
    12 1/4
    3377.0
    1.85
    LOT
    LINER
    7
    4025.0
    8 1/2
    4025.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1
    1.03
    WATER BASED
    23.07.1987
    461
    1.02
    WATER BASED
    22.07.1987
    550
    1.03
    WATER BASED
    23.07.1987
    550
    1.06
    WATER BASED
    27.07.1987
    556
    1.06
    WATER BASED
    27.07.1987
    649
    1.00
    6.0
    03WATER BASED
    28.07.1987
    1026
    1.06
    OIL BASED
    29.07.1987
    1026
    1.06
    WATER BASED
    03.08.1987
    1026
    1.30
    WATER BASED
    03.08.1987
    1026
    1.32
    WATER BASED
    03.08.1987
    1180
    1.26
    10.0
    14.4
    WATER BASED
    10.08.1987
    1335
    1.26
    16.0
    27.8
    WATER BASED
    10.08.1987
    1335
    1.26
    16.0
    27.8
    WATER BASED
    11.08.1987
    1350
    1.30
    11.0
    28.3
    WATER BASED
    13.08.1987
    1350
    1.26
    16.0
    23.0
    WATER BASED
    11.08.1987
    1350
    1.26
    14.0
    15.4
    WATER BASED
    11.08.1987
    1350
    1.26
    12.0
    31.1
    WATER BASED
    12.08.1987
    1350
    1.30
    13.0
    29.7
    WATER BASED
    18.08.1987
    1350
    1.30
    13.0
    26.8
    WATER BASED
    18.08.1987
    1350
    1.30
    18.0
    23.5
    WATER BASED
    19.08.1987
    1350
    1.30
    12.0
    34.5
    WATER BASED
    14.08.1987
    1350
    1.30
    13.0
    29.2
    WATER BASED
    18.08.1987
    2195
    1.20
    26.0
    8.6
    WATER BASED
    20.08.1987
    2310
    1.20
    18.0
    8.6
    WATER BASED
    21.08.1987
    2343
    1.20
    23.0
    7.7
    WATER BASED
    24.08.1987
    2442
    1.20
    25.0
    8.1
    WATER BASED
    24.08.1987
    2544
    1.20
    26.0
    8.6
    WATER BASED
    24.08.1987
    2559
    1.22
    32.0
    9.1
    WATER BASED
    25.08.1987
    2631
    1.24
    25.0
    10.5
    WATER BASED
    26.08.1987
    2685
    1.20
    27.0
    9.6
    WATER BASED
    27.08.1987
    2738
    1.20
    27.0
    9.6
    WATER BASED
    28.08.1987
    2788
    1.20
    31.0
    11.0
    WATER BASED
    31.08.1987
    2886
    1.20
    28.0
    12.5
    WATER BASED
    31.08.1987
    2934
    1.20
    24.0
    12.5
    WATER BASED
    31.08.1987
    2950
    1.22
    25.0
    12.0
    WATER BASED
    03.09.1987
    2950
    1.22
    25.0
    11.0
    WATER BASED
    03.09.1987
    2950
    1.22
    33.0
    12.5
    WATER BASED
    04.09.1987
    2950
    1.22
    25.0
    12.0
    WATER BASED
    07.09.1987
    2950
    1.22
    23.0
    11.0
    WATER BASED
    07.09.1987
    2950
    1.22
    23.0
    12.0
    WATER BASED
    07.09.1987
    3377
    1.43
    28.0
    11.0
    WATER BASED
    09.09.1987
    3377
    1.51
    25.0
    8.6
    WATER BASED
    09.09.1987
    3377
    1.54
    30.0
    11.0
    WATER BASED
    10.09.1987
    3377
    1.57
    29.0
    10.0
    WATER BASED
    11.09.1987
    3377
    1.57
    29.0
    12.0
    WATER BASED
    14.09.1987
    3377
    1.57
    28.0
    10.5
    WATER BASED
    14.09.1987
    3377
    1.57
    29.0
    9.1
    WATER BASED
    16.09.1987
    3377
    1.62
    43.0
    1.1
    WATER BASED
    18.09.1987
    3377
    1.57
    33.0
    14.4
    WATER BASED
    14.09.1987
    3377
    1.58
    23.0
    6.7
    WATER BASED
    07.10.1987
    3377
    1.58
    15.0
    6.2
    WATER BASED
    08.10.1987
    3377
    1.58
    16.0
    4.8
    WATER BASED
    09.10.1987
    3379
    1.62
    33.0
    8.6
    WATER BASED
    21.09.1987
    3398
    1.62
    27.0
    7.2
    WATER BASED
    21.09.1987
    3417
    1.62
    28.0
    6.7
    WATER BASED
    21.09.1987
    3438
    1.62
    22.0
    6.7
    WATER BASED
    21.09.1987
    3461
    1.62
    31.0
    8.1
    WATER BASED
    22.09.1987
    3488
    1.62
    30.0
    8.1
    WATER BASED
    23.09.1987
    3504
    1.62
    30.0
    7.7
    WATER BASED
    24.09.1987
    3521
    1.62
    25.0
    7.7
    WATER BASED
    25.09.1987
    3580
    1.62
    25.0
    9.1
    WATER BASED
    28.09.1987
    3682
    1.62
    25.0
    9.6
    WATER BASED
    28.09.1987
    3719
    1.62
    22.0
    7.7
    WATER BASED
    28.09.1987
    3774
    1.62
    24.0
    9.6
    WATER BASED
    29.09.1987
    3787
    1.62
    18.0
    8.1
    WATER BASED
    01.10.1987
    3835
    1.62
    22.0
    9.6
    WATER BASED
    30.09.1987
    3961
    1.62
    20.0
    6.2
    WATER BASED
    05.10.1987
    3962
    1.58
    25.0
    7.7
    WATER BASED
    06.10.1987
    4025
    1.62
    15.0
    4.8
    WATER BASED
    05.10.1987
    4025
    1.62
    15.4
    4.8
    WATER BASED
    05.10.1987
    4025
    1.58
    20.0
    6.7
    WATER BASED
    05.10.1987

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3043.36
    [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
    0.23