Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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35/3-1

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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.
    35/3-1
    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
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    35/3-1
    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.
    Saga Petroleum ASA
    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.
    162-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.
    100
    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,
    19.07.1976
    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.
    26.10.1976
    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.
    26.10.1978
    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.
    11.02.2005
    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
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    304.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4475.0
    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).
    4469.6
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    12.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    126
    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 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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 50' 41.89'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 43' 41.36'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6857289.00
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    538333.83
    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.
    432

  • Wellbore history
    The exploratory well, 35/3-1, was drilled on block 35/3 in the northern Norwegian North Sea, approximately 65 km west of Måløy in western Norway. The location is east of the Norwegian Trench. The general objective was to test the total stratigraphical sequence down to pre-Jurassic strata. Within the sequence, sand development was predicted for the Lower Cretaceous and the Early Jurassic, with a possibility for minor sands in Middle-Late Jurassic. The well should penetrate two seismic reflectors believed to represent top Early-pre Jurassic and basement, respectively. Planned TD was at 5250 m.
    Operations and results
    Wildcat well 35/3-1 was spudded with the semi-submersible installation Deepsea Saga on 19 July 1976. The well was terminated at 4475 m in the Dunlin Group (Middle Jurassic, Bajocian age). This was not the planned TD, but due to high pressure the well was abandoned at this depth for safety reasons. Because of this the two deep seismic reflectors were not tested in this well. The well was drilled with seawater and salt water gel/Milben mud down to 982 m, with gypsum mud from 982 m to 2474 m, and with lignosulphonate mud from 2474 m to TD.
    A number of Tertiary sands not normally encountered in this part of the North Sea, were penetrated in this well. In the Early Jurassic, at 3805 m, a 215 m sequence of Agat Formation sandstone was penetrated. At 4145 m a 21 m sequence of Late Jurassic Intra Heather Formation sandstone was penetrated. Shows were encountered and described as follows:
    "The first traces of hydrocarbons were encountered in Early Cretaceous sand at 3865 m. The sand gave a poor show of dead oil with no direct fluorescence, but with slow, streaming, cream cut fluorescence. Similar shows were occasionally encountered over the interval 3865 - 3975 m, partly with a fast, streaming, white cut fluorescence. At 3900 m a relatively clean, fine to medium grained silica cemented sand showed light brown stain, traces of pale yellow fluorescence, and fast, streaming, white cut fluorescence. In the Jurassic, two sand beds around 4220 m had a fair gas show of 350,000 ppm C1, 35000 ppm C2, and 13000 ppm C3 as recorded in The Analyst's unit. The sand had no stain and no direct fluorescence, but showed some scattered white cut fluorescence. A dirty sand stringer at 4225 m showed 130000 ppm C1, 23000 ppm C2 and 9500 C3, with associated scattered white cut fluorescence. General background gas in the Jurassic was 1000 ppm total."
    Geochemical analyses showed oil maturity below ca 3200 m (%Ro > 0.5). Below ca 4100 m analyses showed abundant light hydrocarbons, indicating condensate/gas generation from Heather shales below this depth. These shales had 1.9% organic carbon on average, representing a massive source rock for condensate and gas. No conventional cores were cut and no fluid sample taken. Fifty-one sidewall cores were recovered from 2975 m to TD.
    The well was plugged and abandoned on 26 October as a 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]
    520.00
    4475.00

  • 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
    505.0
    36
    507.0
    0.00
    LOT
    SURF.COND.
    20
    969.0
    26
    970.0
    0.00
    LOT
    INTERM.
    13 3/8
    2465.0
    17 1/2
    2466.0
    1.77
    LOT
    INTERM.
    9 5/8
    4180.0
    12 1/4
    4182.0
    2.04
    LOT
    OPEN HOLE
    4475.0
    8 1/2
    4475.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC SONIC GR
    503
    2472
    CBL
    321
    4176
    CBL
    325
    2461
    FDC CNL GR
    4176
    4471
    FDC GR
    503
    4182
    HDT
    0
    0
    HDT
    2462
    4471
    IES
    503
    2474
    ISF SONIC GR
    2461
    4468
    MLL ML
    4176
    4471
    VELOCITY
    375
    4470

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.56

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.62

  • 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
    12.11
    pdf
    3.08

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    510
    0.00
    seawater
    819
    1.10
    68.0
    58.0
    water based
    2306
    1.19
    53.0
    30.0
    water based
    2622
    1.31
    46.0
    18.0
    water based
    3139
    1.35
    48.0
    5.0
    water based
    4202
    1.37
    46.0
    5.0
    water based
    4313
    1.80
    49.0
    4.0
    water based

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2530.0
    [m]
    DC
    RRI
    2545.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2575.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2605.0
    [m]
    DC
    RRI
    2617.0
    [m]
    DC
    RRI
    2635.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2665.0
    [m]
    DC
    RRI
    2680.0
    [m]
    DC
    RRI
    2695.0
    [m]
    DC
    RRI
    2710.0
    [m]
    DC
    RRI
    2725.0
    [m]
    DC
    RRI
    2740.0
    [m]
    DC
    RRI
    2755.0
    [m]
    DC
    RRI
    2770.0
    [m]
    DC
    RRI
    2785.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    RRI
    2815.0
    [m]
    DC
    RRI
    2830.0
    [m]
    DC
    RRI
    2845.0
    [m]
    DC
    RRI
    2860.0
    [m]
    DC
    RRI
    2875.0
    [m]
    DC
    RRI
    2890.0
    [m]
    DC
    RRI
    2905.0
    [m]
    DC
    RRI
    2920.0
    [m]
    DC
    RRI
    2935.0
    [m]
    DC
    RRI
    2950.0
    [m]
    DC
    RRI
    2965.0
    [m]
    DC
    RRI
    2980.0
    [m]
    DC
    RRI
    2995.0
    [m]
    DC
    RRI
    3010.0
    [m]
    DC
    RRI
    3025.0
    [m]
    DC
    RRI
    3037.0
    [m]
    DC
    RRI
    3055.0
    [m]
    DC
    RRI
    3070.0
    [m]
    DC
    RRI
    3085.0
    [m]
    DC
    RRI
    3100.0
    [m]
    DC
    RRI
    3115.0
    [m]
    DC
    RRI
    3130.0
    [m]
    DC
    RRI
    3145.0
    [m]
    DC
    RRI
    3160.0
    [m]
    DC
    RRI
    3175.0
    [m]
    DC
    RRI
    3190.0
    [m]
    DC
    RRI
    3205.0
    [m]
    DC
    RRI
    3220.0
    [m]
    DC
    RRI
    3235.0
    [m]
    DC
    RRI
    3250.0
    [m]
    DC
    RRI
    3265.0
    [m]
    DC
    RRI
    3280.0
    [m]
    DC
    RRI
    3295.0
    [m]
    DC
    RRI
    3310.0
    [m]
    DC
    RRI
    3325.0
    [m]
    DC
    RRI
    3340.0
    [m]
    DC
    RRI
    3355.0
    [m]
    DC
    RRI
    3370.0
    [m]
    DC
    RRI
    3385.0
    [m]
    DC
    RRI
    3400.0
    [m]
    DC
    RRI
    3415.0
    [m]
    DC
    RRI
    3430.0
    [m]
    DC
    RRI
    3460.0
    [m]
    DC
    RRI
    3475.0
    [m]
    DC
    RRI
    3490.0
    [m]
    DC
    RRI
    3505.0
    [m]
    DC
    RRI
    3520.0
    [m]
    DC
    RRI
    3535.0
    [m]
    DC
    RRI
    3550.0
    [m]
    DC
    RRI
    3565.0
    [m]
    DC
    RRI
    3595.0
    [m]
    DC
    RRI
    3615.0
    [m]
    DC
    RRI
    3630.0
    [m]
    DC
    RRI
    3645.0
    [m]
    DC
    RRI
    3690.0
    [m]
    DC
    RRI
    3720.0
    [m]
    DC
    RRI
    3750.0
    [m]
    DC
    RRI
    3780.0
    [m]
    DC
    RRI
    3810.0
    [m]
    DC
    RRI
    3837.0
    [m]
    DC
    RRI
    3870.0
    [m]
    DC
    RRI
    3900.0
    [m]
    DC
    RRI
    3930.0
    [m]
    DC
    RRI
    3960.0
    [m]
    DC
    RRI
    3990.0
    [m]
    DC
    RRI
    4020.0
    [m]
    DC
    RRI
    4050.0
    [m]
    DC
    RRI
    4080.0
    [m]
    DC
    RRI
    4110.0
    [m]
    DC
    RRI
    4140.0
    [m]
    DC
    RRI