Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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31.12.2024 - 01:26
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7435/12-1

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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.
    7435/12-1
    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
    Press release
    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.
    BARENTS 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.
    7435/12-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST14005T15: Inline 7833. X-Line 7829
    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.
    Statoil Petroleum 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.
    1667-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.
    24
    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,
    09.08.2017
    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.
    01.09.2017
    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.
    01.09.2019
    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.
    01.09.2019
    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
    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.
    STØ 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.
    MIDDLE TRIASSIC
    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.
    KOBBE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    32.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    253.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1540.0
    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).
    1539.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    54
    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.
    MIDDLE 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.
    KOBBE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    74° 4' 18.21'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    35° 48' 31.06'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8222886.96
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    402277.88
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    37
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    8228

  • Wellbore history
    General
    Well 7435/12-1 was drilled to test the Korpfjell prospect on the Haapet Dome far east on the Bjarmeland Platform in the Barents Sea. The primary objective was to test the hydrocarbon potential, phase and source in the Realgrunnen Subgroup (Stø-Tubåen-Fruholmen formations). Secondary objective was to test the hydrocarbon potential in the Triassic Snadd and Kobbe formations.
    Operations and results
    The Korpfjell pilot well 7435/12-U-1 was spudded on 7 August 2017 and drilled as a vertical 9 7/8" hole. TD was set at 547 m in the Hekkingen Formation. The pilot hole confirmed the geological prognosis and proved no shallow hydrocarbons above the setting depth of the 10 3/4" surface casing in the main well.
    Wildcat well 7435/12-1 was spudded with the semi-submersible installation Songa Enabler on 9 August 2017 and drilled to TD at 1540 m in the Middle Triassic Kobbe Formation. Operations proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 306 m and with KCL Polymer/Gem water-based mud from 306 m to TD.
    The Hekkingen Formation was drilled without riser and no samples were available for analysis. However, high gamma ray readings indicate source rock with elevated organic content. Coal samples from the Nordmela and Snadd formations show very high TOC concentrations >50 wt% and together with elevated HI of 230 – 340 mg HC/g TOC, they have potential for gas and possibly some oil.
    Sandstones in the primary target, in the Realgrunnen Subgroup, was encountered at 576.5 m. The  reservoir proved to be hydrocarbon bearing, with a 34 m gas column in sandstones of good to moderate reservoir quality in the Stø and  Nordmela formations. The gas-water contact is at 612 m. The deeper secondary targets in the Triassic Snadd and Kobbe formations were encountered at 779.5 m and 1168, respectively. Dry gas was found in thin sandstones in the Kobbe Formation with the highest mud gas readings from top Kobbe down to 1226 m. The reservoir quality in Kobbe was poor with only 2.4 m net reservoir.
    Evaluation of diagenetic minerals and vitrinite reflectance indicate erosion and uplift in the area in the range 1.2 to 2.2 km. The well was almost devoid of oil shows. Only very weak shows were described in one spot sample from 584.5 m in the uppermost Nordmela Formation and from ditch cuttings in the interval 1293 – 1317 m MD in the Kobbe Formation.
    One core was cut from 583.7 to 628.8 m in the Nordmela Formation with 99.3% recovery. MDT fluid samples were taken in the Nordmela Formation at 588.8 m (gas), 611.0 m (gas), and 616.5 m (water). MDT sampling was attempted also in the Snadd and Kobbe formations, but no sample was acquired.
    The well was permanently abandoned on 1 September 2017 as a gas discovery.
    Testing
    No drill stem test was performed.

  • 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]
    550.00
    1539.00

  • 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
    583.7
    628.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    44.8
    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
    545.2
    [m]
    SWC
    CGG
    546.3
    [m]
    SWC
    CGG
    550.0
    [m]
    DC
    CGG
    553.0
    [m]
    DC
    CGG
    554.0
    [m]
    SWC
    CGG
    556.0
    [m]
    DC
    CGG
    562.0
    [m]
    DC
    CGG
    563.0
    [m]
    SWC
    CGG
    568.0
    [m]
    DC
    CGG
    568.0
    [m]
    SWC
    CGG
    574.0
    [m]
    DC
    CGG
    574.0
    [m]
    SWC
    CGG
    577.0
    [m]
    DC
    CGG
    579.0
    [m]
    SWC
    CGG
    580.0
    [m]
    DC
    CGG
    583.0
    [m]
    DC
    CGG
    584.2
    [m]
    C
    CGG
    585.4
    [m]
    C
    CGG
    587.8
    [m]
    C
    CGG
    589.3
    [m]
    C
    CGG
    592.9
    [m]
    C
    CGG
    597.1
    [m]
    C
    CGG
    602.3
    [m]
    C
    CGG
    607.6
    [m]
    C
    CGG
    613.6
    [m]
    C
    CGG
    618.8
    [m]
    C
    CGG
    623.9
    [m]
    C
    CGG
    626.8
    [m]
    C
    CGG
    631.0
    [m]
    DC
    CGG
    637.0
    [m]
    DC
    CGG
    643.0
    [m]
    DC
    CGG
    645.0
    [m]
    SWC
    CGG
    649.0
    [m]
    DC
    CGG
    651.0
    [m]
    SWC
    CGG
    655.0
    [m]
    SWC
    CGG
    655.0
    [m]
    DC
    CGG
    661.0
    [m]
    DC
    CGG
    667.0
    [m]
    DC
    CGG
    673.0
    [m]
    DC
    CGG
    679.0
    [m]
    DC
    CGG
    685.0
    [m]
    DC
    CGG
    691.0
    [m]
    DC
    CGG
    703.0
    [m]
    DC
    CGG
    712.0
    [m]
    DC
    CGG
    721.0
    [m]
    DC
    CGG
    730.0
    [m]
    DC
    CGG
    739.0
    [m]
    DC
    CGG
    748.0
    [m]
    DC
    CGG
    752.9
    [m]
    SWC
    CGG
    757.0
    [m]
    DC
    CGG
    766.0
    [m]
    DC
    CGG
    775.0
    [m]
    DC
    CGG
    784.0
    [m]
    SWC
    CGG
    784.0
    [m]
    DC
    CGG
    793.0
    [m]
    DC
    CGG
    802.0
    [m]
    DC
    CGG
    813.0
    [m]
    DC
    CGG
    822.0
    [m]
    DC
    CGG
    831.0
    [m]
    DC
    CGG
    840.0
    [m]
    DC
    CGG
    849.0
    [m]
    DC
    CGG
    858.0
    [m]
    DC
    CGG
    867.0
    [m]
    DC
    CGG
    876.0
    [m]
    DC
    CGG
    885.0
    [m]
    DC
    CGG
    894.0
    [m]
    DC
    CGG
    903.0
    [m]
    DC
    CGG
    912.0
    [m]
    DC
    CGG
    921.0
    [m]
    DC
    CGG
    930.0
    [m]
    DC
    CGG
    939.0
    [m]
    DC
    CGG
    948.0
    [m]
    DC
    CGG
    957.0
    [m]
    DC
    CGG
    966.0
    [m]
    DC
    CGG
    975.0
    [m]
    DC
    CGG
    984.0
    [m]
    DC
    CGG
    993.0
    [m]
    DC
    CGG
    1002.0
    [m]
    DC
    CGG
    1011.0
    [m]
    DC
    CGG
    1020.0
    [m]
    DC
    CGG
    1029.0
    [m]
    DC
    CGG
    1038.0
    [m]
    DC
    CGG
    1046.0
    [m]
    DC
    CGG
    1047.0
    [m]
    DC
    CGG
    1056.0
    [m]
    DC
    CGG
    1065.0
    [m]
    DC
    CGG
    1074.0
    [m]
    DC
    CGG
    1083.0
    [m]
    DC
    CGG
    1092.0
    [m]
    DC
    CGG
    1101.0
    [m]
    DC
    CGG
    1110.0
    [m]
    DC
    CGG
    1119.0
    [m]
    DC
    CGG
    1128.0
    [m]
    DC
    CGG
    1137.0
    [m]
    DC
    CGG
    1146.0
    [m]
    DC
    CGG
    1155.0
    [m]
    DC
    CGG
    1164.0
    [m]
    DC
    CGG
    1173.0
    [m]
    DC
    CGG
    1182.0
    [m]
    DC
    CGG
    1191.0
    [m]
    DC
    CGG
    1200.0
    [m]
    DC
    CGG
    1212.0
    [m]
    DC
    CGG
    1221.0
    [m]
    DC
    CGG
    1236.0
    [m]
    DC
    CGG
    1245.0
    [m]
    DC
    CGG
    1254.0
    [m]
    DC
    CGG
    1263.0
    [m]
    DC
    CGG
    1272.0
    [m]
    DC
    CGG
    1281.0
    [m]
    DC
    CGG
    1288.6
    [m]
    SWC
    CGG
    1290.0
    [m]
    DC
    CGG
    1299.0
    [m]
    DC
    CGG
    1308.0
    [m]
    DC
    CGG
    1317.0
    [m]
    DC
    CGG
    1326.0
    [m]
    DC
    CGG
    1335.0
    [m]
    DC
    CGG
    1344.0
    [m]
    DC
    CGG
    1353.0
    [m]
    DC
    CGG
    1362.0
    [m]
    DC
    CGG
    1371.0
    [m]
    DC
    CGG
    1380.0
    [m]
    DC
    CGG
    1389.0
    [m]
    DC
    CGG
    1398.0
    [m]
    DC
    CGG
    1407.0
    [m]
    DC
    CGG
    1416.0
    [m]
    DC
    CGG
    1425.0
    [m]
    DC
    CGG
    1434.0
    [m]
    DC
    CGG
    1443.0
    [m]
    DC
    CGG
    1452.0
    [m]
    DC
    CGG
    1461.0
    [m]
    DC
    CGG
    1470.0
    [m]
    DC
    CGG
    1479.0
    [m]
    DC
    CGG
    1488.0
    [m]
    DC
    CGG
    1497.0
    [m]
    DC
    CGG
    1506.0
    [m]
    DC
    CGG
    1515.0
    [m]
    DC
    CGG
    1524.0
    [m]
    DC
    CGG
    1533.0
    [m]
    DC
    CGG
    1539.0
    [m]
    DC
    CGG
    8980.0
    [ft]
    DC

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI MSIP
    1536
    1536
    FMI MSIP GR
    290
    791
    HRLA PEX ECS GR
    521
    803
    IBC CBL GR
    280
    536
    MDT
    824
    1205
    MDT GR
    576
    578
    MDT GR
    578
    581
    MDT GR
    579
    781
    MSCT
    810
    1398
    MSCT
    861
    1204
    MWD - ARC TELE
    285
    545
    MWD - GVR ARC TELE
    545
    805
    MWD - MICROS IMP
    805
    1540
    PEX HRLA ECS
    798
    1529
    USIT CBL GR
    288
    530
    XL ROCK GR
    544
    794
    XL ROCK GR
    651
    794
    ZO VSP
    220
    1500

  • 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
    27
    290.0
    30
    290.0
    0.00
    536.0
    0.0
    1.45
    FIT
    INTERM.
    10 3/4
    538.4
    14 3/4
    548.0
    0.00
    787.4
    0.0
    1.95
    LOT
    LINER
    7 5/8
    799.3
    9 1/2
    808.0
    0.00
    OPEN HOLE
    1540.0
    6 1/2
    1540.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    308
    1.03
    9.0
    Spud Mud
    420
    1.24
    17.0
    KCl/Polymer/GEM
    420
    1.22
    16.0
    KCl/Polymer/GEM
    545
    1.15
    12.0
    KCl/Polymer/GEM
    545
    1.03
    8.0
    Spud Mud
    581
    1.15
    14.0
    KCl/Polymer/GEM
    697
    1.20
    16.0
    KCl/Polymer/GEM
    715
    1.15
    16.0
    KCl/Polymer/GEM
    805
    1.15
    14.0
    KCl/Polymer/GEM
    805
    1.18
    16.0
    KCl/Polymer/GEM
    940
    1.18
    17.0
    KCl/Polymer/GEM
    1240
    1.20
    20.0
    KCl/Polymer/GEM
    1255
    1.18
    19.0
    KCl/Polymer/GEM
    1540
    1.20
    20.0
    KCl/Polymer/GEM