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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2/4-16

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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.
    2/4-16
    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.
    SUSPENDED
    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.
    2/4-16
    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.
    680-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.
    182
    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,
    07.05.1991
    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.
    04.11.1991
    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.
    04.11.1993
    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.
    18.01.2007
    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.
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    67.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4996.0
    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).
    4995.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    172
    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.
    BRYNE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 40' 39.41'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 9' 2.9'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6281650.56
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    509240.64
    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.
    1702

  • Wellbore history
    General
    Well 2/4-16 was drilled on the eastern margin of the Feda Graben North of the Albuskjell and Ekofisk Fields in the North Sea. Geologically the area consists of three sub-platforms. These are separated by large NW-SE striking normal faults down-faulted to the southwest and stepping down to the Feda Graben in the southern part of the block. The 2/4-16 well is located in the centre of the licence area on the same down faulted segment as the blowout wells 2/4-13, -14 and -15. Shallow gas was predicted from seismic anomalies at 10 different levels, and several precautions and actions were carried out to be able to handle potential gas-charged shallow gas.
    The main objective for the well was to test the Late Jurassic, expected to contain a thick sand resting unconformable on the Middle Jurassic. This objective was the basis also for the 2/4-14 well. A secondary objective for the well was to penetrate the Middle Jurassic and 150 m into the Triassic sequence to test for possible hydrocarbon bearing sandstones sequences.
    Operations and results
    Wildcat well was spudded with the semi-submersible installation Treasure Saga on 7 May 1991 and drilled to TD at 4996 m in the Middle Jurassic Bryne Formation. Shallow gas was detected at 522, 606, 628 and 675 m during drilling of 9 7/8" pilot hole. While drilling through very hard chalk rocks in the 12,6" section severe problems with the drilling equipment was experienced. The hard rocks also caused 8.5 days of delay due to ten washouts and fishing jobs. In addition the vibration together with high temperature caused twelve failures to the MWD tools, and also problems related to equipment deliveries. When drilling down to 4996 m the top drive saver sub had to be changed out due to a washout. During change of saver sub, the well started flowing uncontrolled up through the drill string, and the drill pipe was cut with the shear ram. Fifty-eight days were spent from shearing the pipe until temporary abandoning the well was decided. The well was drilled with spud mud down to 424 m, with gel mud from 424 m to 951 m, with KCl mud from 951 m to 4726 m, with a reduced ph water based mud from 4726 m to 4910 m, and with HI TEMP Polymer mud from 4910 m to TD.
    A detailed study of the logs indicated no gas in the sand beds at 497 m and 832 m. Gas peaks were observed only on the MWD in the following thin sand beds from: 520.8 - 521.5 m, 604.5 - 606.2 m, 625 - 626 m and 675.5 - 676.1 m. This was later verified on the wire line logs, with a 3 m depth shift. This was interpreted as "original" gas, as similar observations were experienced at similar depths (520, 605 and 625 m in wells 2/4-13, 14 and 15).
    There were no hydrocarbon indications from the logs in the well. The only indications from sidewall cores were some very weak shows in 3140 to 3155 m in the Balder Formation. Post-well organic geochemical analyses also reported migrant hydrocarbons in the interval 4638 to 4737 m in the Cromer Knoll Group.
    The 2/4-16 well consisted of a 3341 m thick Cenozoic sequence. The Late Miocene to Pliocene Nordland Group was mainly composed of sand and clay down to 900 m. The rest of the Nordland Group and the Hordaland Group was dominated by claystones with thin beds of sandstone and limestone. The Late Paleocene Rogaland Group at 3140 m consisted of the characteristic tuffaceous claystone in the upper part. The middle part was dominated by claystone with traces of limestone/dolomite becoming claystone interbedded with limestone and marl downwards. The 1321 m thick chalk sequence of the Shetland Group rested unconformable on claystone and marl of the Early Cretaceous Cromer Knoll Group. The 140 m thick Tyne Group was dominated by claystones and siltstones with thin beds of limestone/dolomite. The final section above TD was 119 m of Vestland Group siltstones and shales with minor sand and coal beds.
    No conventional cores were cut and no wire line fluid samples taken. A total of 371 sidewall cores were attempted, of which 147 were recovered.
    Due to the gas kick at 4996 m the well was terminated without having reached the Triassic target. The well was suspended on 4 November 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]
    430.00
    4996.00

  • 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
    167.0
    36
    170.0
    0.00
    LOT
    INTERM.
    24
    410.0
    30
    424.0
    1.44
    LOT
    INTERM.
    18 5/8
    937.0
    24
    951.0
    1.85
    LOT
    INTERM.
    14
    2897.0
    17 1/2
    2912.0
    1.93
    LOT
    INTERM.
    10 3/4
    4632.0
    12 1/2
    4650.0
    2.20
    LOT
    INTERM.
    7 5/8
    4892.0
    9 1/2
    4910.0
    2.35
    LOT
    OPEN HOLE
    4963.0
    6
    4996.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    2890
    4650
    CBL VDL GR
    2890
    4650
    CST GR
    2890
    4650
    CST GR
    4634
    4910
    DIL LSS MSFL GR SP
    409
    948
    DIS MSDL LSS GR AMS
    4634
    4910
    DLL LSS MSFL GR SP
    936
    2899
    DLL LSS MSFL GR SP
    2890
    4650
    LDL CNL GR
    409
    948
    LDL CNL GR AMS
    2890
    4650
    LDL CNL GR AMS
    4634
    4910
    LDL GR CAL
    936
    2899
    MSCT
    4634
    4910
    MWD - GR RES DIR TEMP
    170
    4910
    RFT
    409
    948
    RFT GR TLC AMS
    4634
    4910
    SHDT GR AMS
    2890
    4650
    SHDT GR AMS
    4634
    4910
    VELOCITY
    1000
    4630

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.82

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.89

  • 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
    40.57

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    424
    1.05
    WATER BASED
    431
    1.27
    11.0
    WATER BASED
    770
    1.27
    4.0
    WATER BASED
    951
    1.25
    14.0
    WATER BASED
    968
    1.39
    31.0
    WATER BASED
    1330
    1.60
    33.0
    WATER BASED
    1335
    1.60
    31.0
    WATER BASED
    1427
    1.70
    39.0
    WATER BASED
    1703
    1.72
    63.0
    WATER BASED
    1991
    1.72
    49.0
    WATER BASED
    2164
    1.72
    66.0
    WATER BASED
    2212
    1.72
    47.0
    WATER BASED
    2488
    1.72
    52.0
    WATER BASED
    2674
    1.72
    47.0
    WATER BASED
    2897
    1.70
    37.0
    WATER BASED
    2912
    1.72
    51.0
    WATER BASED
    2927
    1.72
    40.0
    WATER BASED
    2933
    1.72
    44.0
    WATER BASED
    4089
    1.67
    23.0
    WATER BASED
    4127
    1.67
    25.0
    WATER BASED
    4155
    1.67
    25.0
    WATER BASED
    4188
    1.67
    22.0
    WATER BASED
    4205
    1.67
    24.0
    WATER BASED
    4288
    1.67
    22.0
    WATER BASED
    4305
    1.67
    23.0
    WATER BASED
    4354
    1.67
    24.0
    WATER BASED
    4427
    1.67
    25.0
    WATER BASED
    4428
    1.67
    25.0
    WATER BASED
    4441
    1.67
    25.0
    WATER BASED
    4473
    1.67
    25.0
    WATER BASED
    4491
    1.72
    33.0
    WATER BASED
    4512
    1.75
    35.0
    WATER BASED
    4547
    1.75
    28.0
    WATER BASED
    4583
    1.75
    27.0
    WATER BASED
    4594
    1.80
    29.0
    WATER BASED
    4632
    2.12
    19.0
    WATER BASED
    4650
    1.85
    29.0
    WATER BASED
    4655
    2.00
    28.0
    WATER BASED
    4697
    2.02
    31.0
    WATER BASED
    4726
    2.06
    25.0
    WATER BASED
    4727
    2.06
    26.0
    WATER BASED
    4742
    2.10
    25.0
    WATER BASED
    4754
    2.12
    28.0
    WATER BASED
    4771
    2.12
    23.0
    WATER BASED
    4803
    2.12
    24.0
    WATER BASED
    4838
    2.12
    22.0
    WATER BASED
    4893
    2.12
    24.0
    WATER BASED
    4910
    2.12
    21.0
    WATER BASED
    4914
    2.12
    18.0
    WATER BASED
    4917
    2.12
    18.0
    WATER BASED
    4924
    2.20
    48.0
    WATER BASED
    4935
    2.20
    33.0
    WATER BASED
    4951
    2.12
    29.0
    WATER BASED
    4996
    2.20
    33.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2110.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2450.0
    [m]
    DC
    RRI
    2470.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2510.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    RRI
    2710.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    RRI
    2770.0
    [m]
    DC
    RRI
    2790.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2830.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    RRI
    2870.0
    [m]
    DC
    RRI
    2890.0
    [m]
    DC
    RRI
    2910.0
    [m]
    DC
    RRI
    2930.0
    [m]
    DC
    RRI
    2950.0
    [m]
    DC
    RRI
    2970.0
    [m]
    DC
    RRI
    2990.0
    [m]
    DC
    RRI
    3010.0
    [m]
    DC
    RRI
    3030.0
    [m]
    DC
    RRI
    3050.0
    [m]
    DC
    RRI
    3070.0
    [m]
    DC
    RRI
    3090.0
    [m]
    DC
    RRI
    3110.0
    [m]
    DC
    RRI
    3130.0
    [m]
    DC
    RRI
    3150.0
    [m]
    DC
    RRI
    3170.0
    [m]
    DC
    RRI
    3190.0
    [m]
    DC
    RRI
    3210.0
    [m]
    DC
    RRI
    3230.0
    [m]
    DC
    RRI
    3240.0
    [m]
    DC
    RRI
    3250.0
    [m]
    DC
    RRI
    3270.0
    [m]
    DC
    RRI
    3290.0
    [m]
    DC
    RRI
    3310.0
    [m]
    DC
    RRI
    3330.0
    [m]
    DC
    RRI
    3350.0
    [m]
    DC
    RRI
    3370.0
    [m]
    DC
    RRI
    3390.0
    [m]
    DC
    RRI
    3410.0
    [m]
    DC
    RRI
    3430.0
    [m]
    DC
    RRI
    4600.0
    [m]
    DC
    RRI
    4610.0
    [m]
    DC
    RRI
    4620.0
    [m]
    DC
    RRI
    4630.0
    [m]
    DC
    RRI
    4640.0
    [m]
    DC
    RRI
    4650.0
    [m]
    DC
    RRI
    4660.0
    [m]
    DC
    RRI
    4670.0
    [m]
    DC
    RRI
    4680.0
    [m]
    DC
    RRI
    4690.0
    [m]
    DC
    RRI
    4700.0
    [m]
    DC
    RRI
    4710.0
    [m]
    DC
    RRI
    4720.0
    [m]
    DC
    RRI
    4737.0
    [m]
    DC
    RRI