Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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3/7-3

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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.
    3/7-3
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    3/7-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE ANO 7380 SP: 269.
    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.
    Elf Norge A/S
    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.
    293-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.
    72
    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,
    21.06.1981
    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.
    31.08.1981
    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.
    31.08.1983
    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.
    09.03.2009
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    67.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3540.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    93
    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.
    LATE PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 24' 54.77'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 10' 54.33'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6253058.67
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    572913.12
    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.
    293

  • Wellbore history
    General
    Well 3/7-3 was drilled on a salt diapir in the southern part of the Søgne Basin in the North Sea. The primary target of the well was Danian/Late Cretaceous chalk, which had been found hydrocarbon bearing in the Ekofisk area and in the Danish well Lulu 1. Secondary target was Middle Jurassic sandstones, which had been found hydrocarbon bearing in well 2/6-2. The TD was planned below the top of the Zechstein salt in order to test possible Early Jurassic and/or Triassic sandstones.
    Operations and results
    Wildcat well 3/7-3 was spudded with the semi-submersible installation Dyvi Alpha on 21 June 1981and drilled to TD at 3540 m in the Late Permian Zechstein salt. At 1968 m, in the Late Eocene, a drilling break was experienced and the well started to flow. The flow was killed with a mud weight of 1.55 g/cc. After setting the 13 3/8" casing shoe at 1961 m, the well was controlled after gains and losses with a mud weight of 1.58 g/cc. No other problems were encountered while drilling. The well was drilled with seawater and bentonite down 666 m, with seawater/SST 202/FCL mud from 666 m to 1970 m, and with seawater/FCL/LC mud from 1970 m to TD.
    Tertiary sands with a thickness of 37.5 m were encountered in the Paleocene. They were water bearing. The chalk, which was the main target, was relatively tight and water bearing. At 3325 m a 107 meter thick water bearing sandstone of Latest Jurassic - Earliest Cretaceous age (Kimmeridgian - Berriasian) was encountered. Below this sandstone Kimmeridgian shales rested directly on the Zechstein anhydrite. No shows were noted in the well.
    Three cores were cut; one from 2830 to 2848 m in the Danian chalk (60% recovery) and two in the Beriasian Sandstones from 3337.5 to 3339 m (67% recovery) and from 3339 to 3348 m (100% recovery). No wire line fluid samples were taken.
    The well was permanently abandoned on 31 August 1981as 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]
    180.00
    3522.00

  • 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
    2830.0
    2839.6
    [m ]
    2
    3337.5
    3338.5
    [m ]
    3
    3339.0
    3348.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    19.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2830-2835m
    Core photo at depth: 2835-2839m
    Core photo at depth: 3337-3338m
    Core photo at depth: 3339-3344m
    Core photo at depth: 3344-3348m
    2830-2835m
    2835-2839m
    3337-3338m
    3339-3344m
    3344-3348m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1500.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    AMOCO
    1530.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    AMOCO
    1560.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    AMOCO
    1590.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    AMOCO
    1620.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    AMOCO
    1650.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    AMOCO
    1670.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    AMOCO
    1710.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    AMOCO
    1740.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    AMOCO
    1770.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    AMOCO
    1800.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    AMOCO
    1820.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    AMOCO
    1860.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    AMOCO
    1890.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    AMOCO
    1920.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    AMOCO
    1950.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    AMOCO
    1980.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    AMOCO
    2010.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    AMOCO
    2040.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    AMOCO
    2070.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    AMOCO
    2100.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    AMOCO
    2140.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    AMOCO
    2160.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    AMOCO
    2190.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    AMOCO
    2220.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    AMOCO
    2240.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    AMOCO
    2280.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    AMOCO
    2310.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    AMOCO
    2340.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    AMOCO
    2370.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    AMOCO
    2400.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    AMOCO
    2430.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    AMOCO
    2460.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    AMOCO
    2490.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    AMOCO
    2520.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    AMOCO
    2550.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    AMOCO
    2580.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    AMOCO
    2610.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    AMOCO
    2640.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    AMOCO
    2670.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    AMOCO
    2690.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    AMOCO
    2700.0
    [m]
    DC
    RRI
    2710.0
    [m]
    DC
    RRI
    2710.0
    [m]
    DC
    AMOCO
    2720.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    AMOCO
    2740.0
    [m]
    DC
    RRI
    2740.0
    [m]
    DC
    AMOCO
    2745.0
    [m]
    DC
    AMOCO
    2750.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    AMOCO
    2752.0
    [m]
    DC
    RRI
    2754.0
    [m]
    DC
    AMOCO
    2760.0
    [m]
    DC
    RRI
    2760.0
    [m]
    DC
    AMOCO
    2766.0
    [m]
    DC
    RRI
    2768.0
    [m]
    DC
    AMOCO
    2770.0
    [m]
    DC
    RRI
    2776.0
    [m]
    DC
    RRI
    2776.0
    [m]
    DC
    AMOCO
    2780.0
    [m]
    DC
    RRI
    2784.0
    [m]
    DC
    RRI
    2784.0
    [m]
    DC
    AMOCO
    2792.0
    [m]
    DC
    RRI
    2792.0
    [m]
    DC
    AMOCO
    2796.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    AMOCO
    2808.0
    [m]
    DC
    RRI
    2808.0
    [m]
    DC
    AMOCO
    2810.0
    [m]
    DC
    RRI
    2816.0
    [m]
    DC
    RRI
    2816.0
    [m]
    DC
    AMOCO
    2820.0
    [m]
    DC
    RRI
    2820.0
    [m]
    DC
    AMOCO
    2824.0
    [m]
    DC
    RRI
    2824.0
    [m]
    DC
    AMOCO
    2830.0
    [m]
    DC
    RRI
    2830.0
    [m]
    DC
    AMOCO
    2850.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    AMOCO

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.24
    pdf
    9.17

  • Documents – reported by the production licence (period for duty of secrecy expired)

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    500
    1935
    CBL VDL
    1700
    3242
    HDT
    1971
    3253
    HDT
    3240
    3505
    ISF SONIC GR
    153
    2906
    ISF SONIC NGT
    3244
    3542
    LDL CNL GR
    1961
    3542
    LDL GR
    153
    666
    TEMP
    100
    1500
    TEMP
    378
    1800
    VELOCITY
    2500
    3520

  • 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
    153.0
    36
    153.5
    0.00
    LOT
    SURF.COND.
    20
    653.0
    26
    666.0
    1.65
    LOT
    INTERM.
    13 3/8
    1961.0
    17 1/2
    1970.0
    1.81
    LOT
    INTERM.
    9 5/8
    3241.0
    12 1/4
    3253.0
    2.04
    LOT
    OPEN HOLE
    3540.0
    8 1/2
    3542.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    742
    1.13
    waterbased
    1027
    1.19
    waterbased
    2019
    1.59
    waterbased
    2814
    1.63
    waterbased
    3241
    1.63
    waterbased
    3540
    1.64
    waterbased

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3338.00
    [m ]
    3344.00
    [m ]
    3346.00
    [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
    0.21