Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
12.11.2024 - 01:25
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7335/3-1

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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.
    7335/3-1
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7335/3-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST14005T15 Inline: 4481. Xline: 8373
    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.
    Equinor Energy 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.
    1760-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.
    34
    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,
    13.05.2019
    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.
    15.06.2019
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    15.06.2019
    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.
    28.10.2020
    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.
    30.04.2021
    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.
    DRY
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    31.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    239.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4300.0
    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).
    4300.0
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    TRIASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    HAVERT FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    73° 59' 49.86'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    35° 50' 13.73'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8214534.56
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    402709.14
    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.
    8735

  • Wellbore history
    Well 7335/3-1 was drilled to test the Korpfjell Deep on the Haapet Dome far north-east on the Bjarmeland Platform in the Barents Sea. The prospect is a faulted dome, divided into several segments, separated by faults and saddle points. Well 7335/3-1 was the second well drilled on the structure. The primary objective was to test the Realgrunnen Subgroup within the Kapp Toscana Group in segment B, and if oil is discovered, to acquire enough data to determine commerciality and need of appraisal wells. The secondary objectives were to test 4 deeper targets within the central segments: the Intra Snadd Formation Carnian sandstone, the Kobbe Formation, the Havert Formation and Havert clinoforms. The well should also clarify presence of Late Permian source rocks (Ørret Formation), if feasible. The well was committed to drill to 4000 m MSL.
    Operations and results
    A 9 7/8” pilot well (7335/3-U-1) was drilled ca 26 m southeast of the main well to confirm the stratigraphic depth prognosis in order to prevent riserless drilling into reservoir in main well. The pilot was drilled to 547 m, below setting depth for the 20” casing shoe in the main well. No shallow gas or water flow was observed and the prognosed stratigraphy was confirmed.
    Wildcat well 7335/33-1 was spudded with the semi-submersible installation West Hercules on 13 May 2019 and drilled to TD at 4300 m in the Triassic Havert Formation. Operations proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 537 m, with Glydril mud from 537 to from 1046 m and with Exploradril oil-based mud from 1046 m to TD.
    Water filled reservoir with good reservoir properties was encountered within the Realgrunnen Subgroup. The well encountered sandy but tight intervals within the Havert Formation (primary target) and in the Klappmyss Formation. Tight sands were also encountered within the Kobbe and Snadd formations. The well TD’d above the Permian, so potential source rock within the Ørret Formation was not evaluated.
    No conclusive shows were recorded in the well. Direct fluorescence (no cut) in the interval 980 to 1027 m was observed in carbonaceous claystone in the Snadd Formation. Elevated mud gas was recorded in the same interval. The gas was however dry and believed to be related to the rather extensive coal layers and carbonaceous claystones observed in the ditch cuttings. Other observed fluorescence in the sections that was drilled water-based is interpreted as mineral fluorescence or even due to the glycol additive in the mud. In the oil-based sections no oil shows were observed on cuttings or sidewall cores. Several relative high peaks with very dry gas were however registered in the lower Havert Formation
    No cores were cut. No fluid sample was taken.
    The well was permanently abandoned on 15 June 2019 as a dry well.
    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]
    540.00
    4300.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    540.0
    [m]
    DC
    CGG
    543.0
    [m]
    DC
    CGG
    549.0
    [m]
    DC
    CGG
    555.0
    [m]
    DC
    CGG
    561.0
    [m]
    DC
    CGG
    567.0
    [m]
    DC
    CGG
    573.0
    [m]
    DC
    CGG
    576.0
    [m]
    DC
    CGG
    579.0
    [m]
    DC
    CGG
    582.0
    [m]
    DC
    CGG
    591.0
    [m]
    DC
    CGG
    600.0
    [m]
    DC
    CGG
    609.0
    [m]
    DC
    CGG
    618.0
    [m]
    DC
    CGG
    627.0
    [m]
    DC
    CGG
    636.0
    [m]
    DC
    CGG
    644.0
    [m]
    DC
    CGG
    654.0
    [m]
    DC
    CGG
    663.0
    [m]
    DC
    CGG
    669.0
    [m]
    DC
    CGG
    678.0
    [m]
    DC
    CGG
    687.0
    [m]
    DC
    CGG
    696.0
    [m]
    DC
    CGG
    705.0
    [m]
    DC
    CGG
    714.0
    [m]
    DC
    CGG
    723.0
    [m]
    DC
    CGG
    732.0
    [m]
    DC
    CGG
    741.0
    [m]
    DC
    CGG
    750.0
    [m]
    DC
    CGG
    759.0
    [m]
    DC
    CGG
    768.0
    [m]
    DC
    CGG
    777.0
    [m]
    DC
    CGG
    786.0
    [m]
    DC
    CGG
    795.0
    [m]
    DC
    CGG
    804.0
    [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
    1056.0
    [m]
    DC
    CGG
    1065.0
    [m]
    DC
    CGG
    1077.0
    [m]
    DC
    CGG
    1095.0
    [m]
    DC
    CGG
    1113.0
    [m]
    DC
    CGG
    1131.0
    [m]
    DC
    CGG
    1149.0
    [m]
    DC
    CGG
    1158.0
    [m]
    DC
    CGG
    1167.0
    [m]
    DC
    CGG
    1176.0
    [m]
    DC
    CGG
    1185.0
    [m]
    DC
    CGG
    1194.0
    [m]
    DC
    CGG
    1203.0
    [m]
    DC
    CGG
    1212.0
    [m]
    DC
    CGG
    1221.0
    [m]
    DC
    CGG
    1230.0
    [m]
    DC
    CGG
    1239.0
    [m]
    DC
    CGG
    1266.0
    [m]
    DC
    CGG
    1293.0
    [m]
    DC
    CGG
    1320.0
    [m]
    DC
    CGG
    1347.0
    [m]
    DC
    CGG
    1374.0
    [m]
    DC
    CGG
    1401.0
    [m]
    DC
    CGG
    1428.0
    [m]
    DC
    CGG
    1455.0
    [m]
    DC
    CGG
    1482.0
    [m]
    DC
    CGG
    1509.0
    [m]
    DC
    CGG
    1536.0
    [m]
    DC
    CGG
    1563.0
    [m]
    DC
    CGG
    1590.0
    [m]
    DC
    CGG
    1617.0
    [m]
    DC
    CGG
    1644.0
    [m]
    DC
    CGG
    1671.0
    [m]
    DC
    CGG
    1698.0
    [m]
    DC
    CGG
    1725.0
    [m]
    DC
    CGG
    1752.0
    [m]
    DC
    CGG
    1779.0
    [m]
    DC
    CGG
    1806.0
    [m]
    DC
    CGG
    1833.0
    [m]
    DC
    CGG
    1860.0
    [m]
    DC
    CGG
    1887.0
    [m]
    DC
    CGG
    1914.0
    [m]
    DC
    CGG
    1941.0
    [m]
    DC
    CGG
    1968.0
    [m]
    DC
    CGG
    1995.0
    [m]
    DC
    CGG
    2022.0
    [m]
    DC
    CGG
    2049.0
    [m]
    DC
    CGG
    2076.0
    [m]
    DC
    CGG
    2103.0
    [m]
    DC
    CGG
    2130.0
    [m]
    DC
    CGG
    2157.0
    [m]
    DC
    CGG
    2184.0
    [m]
    DC
    CGG
    2211.0
    [m]
    DC
    CGG
    2238.0
    [m]
    DC
    CGG
    2265.0
    [m]
    DC
    CGG
    2631.4
    [m]
    SWC
    CGG
    2790.0
    [m]
    DC
    CGG
    2826.0
    [m]
    DC
    CGG
    2871.0
    [m]
    DC
    CGG
    2898.0
    [m]
    DC
    CGG
    2925.0
    [m]
    DC
    CGG
    2952.0
    [m]
    DC
    CGG
    2969.0
    [m]
    SWC
    CGG
    2991.0
    [m]
    DC
    CGG
    3018.0
    [m]
    DC
    CGG
    3045.0
    [m]
    DC
    CGG
    3072.0
    [m]
    DC
    CGG
    3099.0
    [m]
    DC
    CGG
    3126.0
    [m]
    DC
    CGG
    3153.0
    [m]
    DC
    CGG
    3180.0
    [m]
    DC
    CGG
    3195.0
    [m]
    SWC
    CGG
    3222.0
    [m]
    DC
    CGG
    3249.0
    [m]
    DC
    CGG
    3276.0
    [m]
    DC
    CGG
    3303.0
    [m]
    DC
    CGG
    3330.0
    [m]
    DC
    CGG
    3357.0
    [m]
    DC
    CGG
    3381.0
    [m]
    DC
    CGG
    3408.0
    [m]
    DC
    CGG
    3431.0
    [m]
    SWC
    CGG
    3444.0
    [m]
    DC
    CGG
    3471.0
    [m]
    DC
    CGG
    3498.0
    [m]
    DC
    CGG
    3525.0
    [m]
    DC
    CGG
    3552.0
    [m]
    DC
    CGG
    3579.0
    [m]
    DC
    CGG
    3606.0
    [m]
    DC
    CGG
    3633.0
    [m]
    DC
    CGG
    3650.0
    [m]
    SWC
    CGG
    3669.0
    [m]
    DC
    CGG
    3696.0
    [m]
    DC
    CGG
    3723.0
    [m]
    DC
    CGG
    3744.0
    [m]
    SWC
    CGG
    3768.0
    [m]
    DC
    CGG
    3795.0
    [m]
    DC
    CGG
    3822.0
    [m]
    DC
    CGG
    3848.0
    [m]
    SWC
    CGG
    3858.0
    [m]
    SWC
    CGG
    3869.4
    [m]
    SWC
    CGG
    3880.0
    [m]
    SWC
    CGG
    3903.0
    [m]
    DC
    CGG
    3930.0
    [m]
    DC
    CGG
    3957.0
    [m]
    DC
    CGG
    3979.0
    [m]
    SWC
    CGG
    4000.0
    [m]
    SWC
    CGG
    4017.0
    [m]
    DC
    CGG
    4044.0
    [m]
    DC
    CGG
    4062.5
    [m]
    SWC
    CGG
    4071.3
    [m]
    SWC
    CGG
    4087.5
    [m]
    SWC
    CGG
    4112.5
    [m]
    SWC
    CGG
    4130.0
    [m]
    DC
    CGG
    4145.0
    [m]
    SWC
    CGG
    4173.0
    [m]
    DC
    CGG
    4199.0
    [m]
    SWC
    CGG
    4224.0
    [m]
    DC
    CGG
    4251.0
    [m]
    DC
    CGG
    4270.2
    [m]
    SWC
    CGG
    4284.0
    [m]
    DC
    CGG
    4300.0
    [m]
    DC
    CGG

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MWD - ARC TELE
    322
    644
    MWD - PD ARC TELE
    644
    1046
    MWD - PD GVR ARC TELE SS ADN WDP
    1046
    2601
    MWD - PD GVR ES TS SS WDP
    2601
    4300
    MWD - TELE
    270
    322
    XLR
    2631
    4270
    ZO VSP
    256
    4279

  • 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
    36
    318.4
    42
    322.6
    0.00
    SURF.COND.
    20
    531.2
    26
    537.0
    1.64
    FIT
    PILOT HOLE
    644.0
    12 1/4
    644.0
    0.00
    INTERM.
    13 5/8
    1040.6
    16
    1046.0
    2.06
    LOT
    INTERM.
    9 5/8
    2600.0
    12 1/4
    2601.0
    1.77
    LOT
    OPEN HOLE
    4300.0
    8 1/2
    4300.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    492
    1.18
    17.5
    Glydril
    492
    1.18
    17.5
    Seawater
    590
    1.14
    14.0
    Glydril
    1041
    1.14
    17.0
    Glydril
    1046
    1.14
    15.0
    EMS 4400
    2380
    1.14
    16.0
    EMS 4400
    2703
    1.14
    17.0
    EMS 4400
    3862
    1.16
    16.0
    EMS 4400
    4035
    1.17
    17.5
    EMS 4400
    4300
    1.18
    17.5
    EMS 4400