Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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16.07.2024 - 01:28
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36/1-1

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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.
    36/1-1
    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
    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.
    36/1-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE ANO 74-18 SP.191
    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.
    128-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.
    37
    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,
    09.05.1975
    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.
    14.06.1975
    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.
    14.06.1977
    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
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    165.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1596.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    38
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 56' 40.36'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 15' 43.86'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6868811.12
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    566230.22
    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.
    435
  • Wellbore history

    General
    Block 36/1 was the most northern and shoreward block to be released by the Norwegian Government at the time well 36/1-1 was drilled. The eastern boundary of the Block 36/1 is only 20 km from near-shore islands and, at the closest point, approximately 26 km from the mainland. Wildcat well 36/1-1 is located northeast of the Agat Discovery, on the eastern side of the Norwegian Trench. The main objective and target was Middle Jurassic sands.
    Operations and results
    Exploratory Well 36/1-1 was spudded with the semi-submersible installation Dyvi Alpha on 9 May 1975 and drilled to a total depth of 1596 meters in metamorphic gneiss. The well was drilled without any serious drilling problems. The mud used was a water based salt-water gel /Milben mud down to 515 m, adding lignosulphonate and CMC from 515 m to TD.
    Sands were encountered in the Early Cretaceous interval from 1219 m to 1359 m. The target Middle Jurassic sandstones were encountered at 1463 m and extended down to top basement at 1568 m. Coal seams were found between 1500 m to 1548 m. No hydrocarbon bearing formations were encountered in the well. Minor quantities of hydrocarbon were recorded in the Cretaceous and Middle Jurassic sections but there were no major shows. It was assumed that the structure on which 36/1-1 was drilled is not an effective trap. Possibly the shales overlying the Middle Jurassic sandstones are too poorly compacted to constitute effective seals. Also, the major easterly bounding fault may bring sands of the Cretaceous against the Middle Jurassic, thus destroying the effectiveness of the trap. One 6.1 m (80 % recovery) conventional core was cut at TD. No fluid sampling was attempted on wire line.
    The well was permanently abandoned as dry on 14 June 1975.
    Testing
    Two drill stem tests were conducted in the Middle Jurassic: DST 1 from 1549.6 m to 1556 m and DST 2 from 1489.6 m to 1496.6 m. No fluid reached the surface in either test. Gas samples were taken from the test string above the water cushion, which was displaced some distance upwards by inflowing mud filtrate and formation fluids. Analyses of these showed maximum 190 ppm methane in the samples from DST 1 and maximum 130 ppm methane with traces of C2+ in DST 2.
  • 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]
    240.79
    1463.00
  • 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
    5210.0
    5230.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    6.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    970.0
    [ft]
    DC
    OD
    1000.0
    [ft]
    DC
    OD
    2100.0
    [ft]
    DC
    RRI
    2170.0
    [ft]
    DC
    RRI
    2230.0
    [ft]
    DC
    RRI
    2310.0
    [ft]
    DC
    RRI
    2380.0
    [ft]
    DC
    RRI
    2440.0
    [ft]
    DC
    RRI
    2520.0
    [ft]
    DC
    RRI
    2570.0
    [ft]
    DC
    RRI
    3100.0
    [ft]
    DC
    RRI
    3190.0
    [ft]
    DC
    RRI
    3310.0
    [ft]
    DC
    RRI
    3410.0
    [ft]
    DC
    RRI
    3500.0
    [ft]
    DC
    RRI
    3500.0
    [ft]
    DC
    OD
    3560.0
    [ft]
    DC
    OD
    3600.0
    [ft]
    DC
    RRI
    3660.0
    [ft]
    DC
    OD
    3700.0
    [ft]
    DC
    RRI
    3720.0
    [ft]
    DC
    OD
    3750.0
    [ft]
    DC
    OD
    3800.0
    [ft]
    DC
    RRI
    3900.0
    [ft]
    DC
    RRI
    3930.0
    [ft]
    DC
    PETROSTR
    3960.0
    [ft]
    DC
    PETROS
    3990.0
    [ft]
    DC
    PETROS
    4000.0
    [ft]
    DC
    RRI
    4020.0
    [ft]
    DC
    PETROS
    4050.0
    [ft]
    DC
    PETROS
    4080.0
    [ft]
    DC
    PETROS
    4100.0
    [ft]
    DC
    RRI
    4110.0
    [ft]
    DC
    PETROS
    4140.0
    [ft]
    DC
    PETROS
    4170.0
    [ft]
    DC
    PETROS
    4200.0
    [ft]
    DC
    PETROS
    4200.0
    [ft]
    DC
    RRI
    4230.0
    [ft]
    DC
    PETROS
    4260.0
    [ft]
    DC
    PETROS
    4290.0
    [ft]
    DC
    PETROS
    4300.0
    [ft]
    DC
    RRI
    4320.0
    [ft]
    DC
    PETROS
    4350.0
    [ft]
    DC
    PETROS
    4380.0
    [ft]
    DC
    PETROS
    4400.0
    [ft]
    DC
    RRI
    4410.0
    [ft]
    DC
    PETROS
    4450.0
    [ft]
    DC
    PETROS
    4470.0
    [ft]
    DC
    PETROS
    4500.0
    [ft]
    DC
    PETROS
    4530.0
    [ft]
    DC
    PETROS
    4560.0
    [ft]
    DC
    PETROS
    4590.0
    [ft]
    DC
    PETROS
    4620.0
    [ft]
    DC
    PETROS
    4650.0
    [ft]
    DC
    PETROS
    4680.0
    [ft]
    DC
    PETROS
    4710.0
    [ft]
    DC
    PETROS
    4740.0
    [ft]
    DC
    PETROS
    4770.0
    [ft]
    DC
    PETROS
    4800.0
    [ft]
    DC
    PETROS
    4810.0
    [ft]
    DC
    PETROS
    4840.0
    [ft]
    DC
    PETROS
    4850.0
    [ft]
    DC
    PETROS
    4860.0
    [ft]
    DC
    PETROS
    4870.0
    [ft]
    DC
    PETROS
    4880.0
    [ft]
    DC
    PETROS
    4890.0
    [ft]
    DC
    PETROS
    4900.0
    [ft]
    DC
    PETROS
    4910.0
    [ft]
    DC
    PETROS
    4920.0
    [ft]
    DC
    PETROS
    4930.0
    [ft]
    DC
    PETROS
    4940.0
    [ft]
    DC
    PETROS
    4950.0
    [ft]
    DC
    PETROS
    4960.0
    [ft]
    DC
    PETROS
    4970.0
    [ft]
    DC
    PETROS
    4980.0
    [ft]
    DC
    PETROS
    4990.0
    [ft]
    DC
    PETROS
    5000.0
    [ft]
    DC
    PETROS
    5010.0
    [ft]
    DC
    PETROS
    5020.0
    [ft]
    DC
    PETROS
    5030.0
    [ft]
    DC
    PETROS
    5040.0
    [ft]
    DC
    PETROS
    5050.0
    [ft]
    DC
    PETROS
    5060.0
    [ft]
    DC
    PETROS
    5070.0
    [ft]
    DC
    PETROS
    5080.0
    [ft]
    DC
    PETROS
    5090.0
    [ft]
    DC
    PETROS
    5100.0
    [ft]
    DC
    PETROS
    5110.0
    [ft]
    DC
    PETROS
    5120.0
    [ft]
    DC
    PETROS
    5130.0
    [ft]
    DC
    PETROS
    5140.0
    [ft]
    DC
    PETROS
    5150.0
    [ft]
    DC
    PETROS
    5160.0
    [ft]
    DC
    PETROS
    5170.0
    [ft]
    DC
    PETROS
    5180.0
    [ft]
    DC
    PETROS
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.22
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.88
  • 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
    24.49
    pdf
    1.93
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1550
    1556
    0.0
    2.0
    1489
    1496
    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
    2.0
    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
    2.0
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    1219
    1569
    CNL FDC GR
    512
    1472
    CNL FDC GR
    1466
    1593
    CONT. DIP
    512
    1472
    CONT.DIP
    1466
    1593
    IES
    288
    513
    IES
    512
    1472
    IES
    1466
    1593
    MLL ML
    1466
    1593
    SONIC GR
    288
    513
    SONIC GR
    512
    1472
    SONIC GR
    1466
    1593
    VELOCITY
    300
    1550
  • 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
    286.0
    36
    290.0
    0.00
    LOT
    SURF.COND.
    20
    511.0
    26
    513.0
    0.00
    LOT
    INTERM.
    13 3/8
    1465.0
    17 1/2
    1470.0
    1.68
    LOT
    INTERM.
    9 5/8
    1596.0
    12 1/4
    1596.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    286
    1.07
    49.0
    15.0
    spud mud
    515
    1.08
    41.0
    12.0
    water based
    751
    1.10
    45.0
    9.0
    water based
    1466
    1.11
    41.0
    8.0
    water based
    1595
    1.23
    42.0
    9.0
    water based