Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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01.11.2024 - 01:26
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2/5-1

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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.
    2/5-1
    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
    Field
    Name of the field the wellbore is related to.
    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.
    2/5-1
    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.
    Amoco Norway Oil Company
    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.
    41-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.
    114
    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,
    01.08.1970
    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.
    22.11.1970
    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.
    22.11.1972
    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.
    02.04.2007
    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.
    OIL
    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.
    PALEOCENE
    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.
    EKOFISK 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.
    LATE CRETACEOUS
    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.
    TOR FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    27.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    68.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3972.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    22
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    125
    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 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.
    FARSUND FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 38' 19.95'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 20' 7.94'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6277378.57
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    520581.27
    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.
    178

  • Wellbore history
    General
    Wildcat well 2/5-1 is located ca 10 km northeast of the Ekofisk Field. It was drilled on an essentially northwest - southeast striking anticlinal seismic structure extending into the adjacent block 2/4.
    The well is Reference Well for the Ekofisk Formation.
    Operations and results
    Well 2/5-1 was spudded with the jack-up installation Orion on 1 August 1970 and drilled to TD at 3972 m in Late Jurassic shales. At 2997 m cones of the bit was lost in the hole and five days were spent fishing for them. The well was planned vertical, and was essentially vertical with maximum deviation 1.5 deg down to 3238 m. From there deviation increased to 7.1 deg at 3639 m, 12.5 deg at 3821 m, 19.2 deg at 3932 m, and 21.9 deg at 3967 m. The well was drilled with seawater and bentonite down to 381 m and with a Drill aid/XP-20 mud with 3- 6 % diesel from 381 m to TD.
    The Danian limestone (Ekofisk Formation) was encountered at 3041. Then a Late Cretaceous succession was penetrated with chalks of the Tor and Hod Formations at 3132 m and 3475 m, respectively, followed by the Blodøks Formation shales at 3551 m and the Hidra Formation chalk at 3594 m. Commercial quantities of hydrocarbons were encountered and tested in the Ekofisk and Tor Formations. The well also penetrated 133 m of Late Jurassic source rock quality shales. Organic geochemical analyses of these shales showed TOC in the range 2 - 4 % and thermal maturity corresponding to late oil window (%Ro around 0.8), in well position.
    Twenty-three conventional cores were cut in the chalk. Ten were cut in the Ekofisk Formation (75.2 m recovered), and thirteen in the Tor Formation (171.6 m recovered). No wire line fluid samples were taken.
    The well was permanently abandoned on 22 November 1970 as an oil discovery.
    Testing
    One open-hole DST and eight DSTs through liner perforation were performed. The open-hole DST (DST 1) tested the interval 3042 - 3101 m in the Ekofisk Formation. It flowed at maximum 209 Sm3 oil /day. The GOR was 190 and the oil gravity was 41.5 deg API.
    The tests through perforations and after acid stimulation (DST 2 to DST 8) revealed flow rates from individual zones up to 731 Sm3 oil /day. This highest flow was obtained in DST 7 through a 24/64" choke from the interval 3154 - 3191 m in the Tor Formation. The gas/oil ratio and oil gravity in this test were 251 Sm3/Sm3 and 41.9 deg API, respectively.
    <

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    141.43
    3971.54

  • 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
    9995.0
    10018.0
    [ft ]
    2
    10021.0
    10034.5
    [ft ]
    3
    10036.0
    10043.0
    [ft ]
    4
    10043.0
    10069.0
    [ft ]
    5
    10069.0
    10101.0
    [ft ]
    6
    10101.0
    10141.0
    [ft ]
    7
    10141.0
    10175.0
    [ft ]
    8
    10175.0
    10204.0
    [ft ]
    9
    10204.0
    10251.0
    [ft ]
    10
    10251.0
    10253.0
    [ft ]
    11
    10291.0
    10314.5
    [ft ]
    12
    10314.5
    10337.0
    [ft ]
    13
    10337.0
    10372.7
    [ft ]
    14
    10387.0
    10415.0
    [ft ]
    15
    10425.0
    10439.0
    [ft ]
    16
    10439.0
    10450.0
    [ft ]
    17
    10450.0
    10479.0
    [ft ]
    18
    10479.0
    10505.0
    [ft ]
    19
    10505.0
    10559.0
    [ft ]
    20
    10559.0
    10616.0
    [ft ]
    21
    10616.0
    10699.0
    [ft ]
    22
    10699.0
    10774.6
    [ft ]
    23
    10789.0
    10878.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    244.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    127.0
    36
    128.0
    0.00
    LOT
    SURF.COND.
    20
    378.0
    26
    378.0
    0.00
    LOT
    INTERM.
    13 3/8
    1591.0
    17 1/2
    1601.0
    0.00
    LOT
    INTERM.
    9 5/8
    3045.0
    12 1/4
    3055.0
    0.00
    LOT
    PROD.
    7
    3327.0
    8 1/2
    3973.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3042
    3101
    0.0
    2.0
    3274
    3277
    0.0
    4.0
    3244
    3248
    0.0
    5.0
    3285
    3234
    0.0
    6.0
    3225
    3234
    0.0
    7.0
    3154
    3191
    0.0
    8.0
    3043
    3056
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    46.000
    121
    2.0
    4.0
    5.0
    6.0
    7.0
    48.000
    48.000
    8.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    209
    223212
    190
    2.0
    4.0
    425
    612000
    256
    5.0
    145
    6.0
    445
    7.0
    159
    203838
    228
    8.0
    230
    65000

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC GR
    378
    3968
    CAL
    378
    1600
    CBL
    110
    3311
    DLL
    3043
    3967
    FDC GR
    1591
    3972
    GR
    122
    378
    HDT
    1591
    3971
    IES
    278
    3971
    MLL-C
    3043
    3362
    NL CCL
    2988
    3311
    VELOCITY
    378
    3968

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.27
    pdf
    1.79
    pdf
    0.76
    pdf
    2.20

  • 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
    6.92
    pdf
    23.39
    pdf
    6.61
    pdf
    6.52
    pdf
    5.19

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    141
    1.14
    40.0
    seawater
    2017
    1.56
    waterbased
    3081
    1.71
    45.0
    waterbased
    3580
    1.63
    50.0
    waterbased
    3811
    1.63
    44.0
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3551.0
    [m]
    DC
    OD
    3560.0
    [m]
    DC
    OD
    3569.0
    [m]
    DC
    OD
    3578.0
    [m]
    DC
    OD
    3587.0
    [m]
    DC
    OD
    3597.0
    [m]
    DC
    OD
    3606.0
    [m]
    DC
    OD
    3615.0
    [m]
    DC
    OD
    3624.0
    [m]
    DC
    OD
    3633.0
    [m]
    DC
    OD
    3642.0
    [m]
    DC
    OD
    3652.0
    [m]
    DC
    OD
    3664.0
    [m]
    DC
    OD
    3673.0
    [m]
    DC
    OD
    3682.0
    [m]
    DC
    OD
    3691.0
    [m]
    DC
    OD
    3703.0
    [m]
    DC
    OD
    3712.0
    [m]
    DC
    OD
    3722.0
    [m]
    DC
    OD
    3731.0
    [m]
    DC
    OD
    3740.0
    [m]
    DC
    OD
    3749.0
    [m]
    DC
    OD
    3758.0
    [m]
    DC
    OD
    3767.0
    [m]
    DC
    OD
    3776.0
    [m]
    DC
    OD
    3786.0
    [m]
    DC
    OD
    3798.0
    [m]
    DC
    OD
    3807.0
    [m]
    DC
    OD
    3816.0
    [m]
    DC
    OD
    3825.0
    [m]
    DC
    OD
    3834.0
    [m]
    DC
    OD
    3844.0
    [m]
    DC
    OD
    3853.0
    [m]
    DC
    OD
    3862.0
    [m]
    DC
    OD
    3871.0
    [m]
    DC
    OD
    3880.0
    [m]
    DC
    OD
    3889.0
    [m]
    DC
    OD
    3898.0
    [m]
    DC
    OD
    3908.0
    [m]
    DC
    OD
    3917.0
    [m]
    DC
    OD
    3926.0
    [m]
    DC
    OD
    3935.0
    [m]
    DC
    OD
    3944.0
    [m]
    DC
    OD
    3953.0
    [m]
    DC
    OD
    3962.0
    [m]
    DC
    OD
    3972.0
    [m]
    DC
    OD

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    10000.00
    [ft ]
    10010.00
    [ft ]
    10018.00
    [ft ]
    10407.00
    [ft ]