Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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35/10-4 S

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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.
    35/10-4 S
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
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    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    35/10-4
    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.
    1711-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.
    58
    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,
    14.08.2018
    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.
    10.10.2018
    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.
    10.10.2020
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    10.10.2018
    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.
    10.10.2020
    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
    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.
    SHOWS
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    363.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4010.0
    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).
    3810.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    34.7
    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.
    COOK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 8' 55.44'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 17' 4.98'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6779548.53
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    515327.82
    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.
    8499

  • Wellbore history
    General
    Well 35/10-4 S was drilled to test the Stålull prospect on the Marflo Spur in the North Sea. The primary objective was to prove petroleum in Middle and Early Jurassic reservoir rocks (the Brent group and the Cook formation). The secondary objectives were to prove hydrocarbons in Late Jurassic reservoir rocks (Intra Viking Group sands), and to test the reservoir potential in the Paleocene (Intra Balder sands/Sele formation).
    Operations and results
    Wildcat well 35/10-4 S was spudded with the semi-submersible installation Deepsea Bergen on 14 August 2018 and drilled to TD at 4010 m (3810 m TVD) m in the Early Jurassic Cook Formation. Operations proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 772 m, with KCl/GEM/polymer mud from 772 m to 1406 m, with XP-07 oil based mud from 1406 m to 3456 m, and with HT XP-07 and BaraECD oil-based mud from m and with MUD from 3456 m to TD.
    In the Paleocene, the well encountered a 17-metre thick water-bearing sand package with good reservoir properties. The Heather Formation came in at 3353 m and consisted of claystone with numerous interlayered sandstones. A total of 10 metres of the top 50 meters was sandstones with poor reservoir quality, and in this interval, there was an oil show (direct and cut fluorescence) at 3370 m, while  live oil was sampled at 3358.3 m. A second sand-rich Intra-Heather interval was penetrated from 3513 to 3556 m, but without any hydrocarbon indications. The Brent group was encountered at 3625 m (3425 m TVD), about 210 metres thick, of which 40 metres are effective reservoir sandstone, mainly with poor to moderate reservoir properties. Top Cook Formation was encountered at 3845 m (3645 m TVD). About 75 metres of the gross 165 m Cook Formation that was drilled in the well was effective reservoir sandstone, mainly with moderate to good reservoir properties. Both Brent and Cook were water-bearing. There were no oil shows in the well other than the show and the oil in the Intra-Heather sands.
    No cores were cut. MDT fluid samples were taken in the Balder Formation at 1798.5 m (two water samples) and in Intra-Heather sandstone at 3358.3 m (three oil samples). PVT analyses prove 26 % to 28 %  OBM contamination in the oil samples.
    The well was permanently abandoned on 10 October 2019 as a dry well with shows.
    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]
    780.00
    4010.00

  • 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
    449.4
    36
    449.4
    0.00
    SURF.COND.
    20
    766.7
    26
    772.0
    1.37
    FIT
    LINER
    17
    1388.0
    17 1/2
    1406.0
    1.87
    FIT
    INTERM.
    13 3/8
    2491.3
    16
    2497.0
    1.72
    FIT
    INTERM.
    9 5/8
    3448.0
    12 1/4
    3456.0
    1.90
    FIT
    OPEN HOLE
    4010.0
    8 1/2
    4010.0
    0.00

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT PEX MSIP XPT
    3449
    4013
    MDT
    1565
    1900
    MDT
    3353
    3402
    MSIP AIT GR
    3375
    4013
    MWD LWD - ARC6 TELE
    3456
    4010
    MWD LWD - ARC9 TELE
    449
    2497
    MWD LWD - ARC9 TELE
    3140
    3456
    MWD LWD - TELE
    363
    449
    MWD LWD - XC ARC9 TELE SS SADN
    2497
    3140
    PEX AIT MSIP
    770
    2497
    PEX AIT MSIP
    2390
    3406
    PEX ECS
    3449
    4012
    USIT CBL
    2720
    3410
    VSP
    359
    2430
    VSP
    2233
    3818
    XLROCK
    3511
    3997
    XPT PEX GR
    3628
    3397

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    752
    1.20
    22.0
    KCl/Polymer/GEM
    875
    1.22
    18.0
    KCl/Polymer/GEM
    875
    1.25
    20.0
    KCl/Polymer/GEM
    1406
    1.35
    37.0
    XP-07
    1406
    1.25
    22.0
    KCl/Polymer/GEM
    1676
    1.36
    22.0
    XP-07
    1706
    1.56
    20.0
    XP-07
    1706
    1.34
    16.0
    XP-07
    1844
    1.35
    26.0
    XP-07
    2277
    1.35
    23.0
    XP-07
    2581
    1.53
    23.0
    XP-07
    2771
    1.60
    23.0
    XP-07
    2843
    1.57
    21.0
    XP-07
    2900
    1.58
    21.0
    XP-07
    3100
    1.82
    39.0
    BaraECD
    3120
    1.55
    17.0
    XP-07
    3350
    1.82
    39.0
    BaraECD
    3405
    1.55
    20.0
    XP-07
    3456
    1.82
    34.0
    XP-07
    3456
    1.55
    19.0
    XP-07
    3530
    1.82
    42.0
    BaraECD
    4010
    1.82
    39.0
    BaraECD