Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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16.07.2024 - 01:28
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3/7-2

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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.
    3/7-2
    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.
    3/7-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    X ANO 7832 SP: 1343 +line ANO738&SP502
    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.
    273-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.
    83
    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,
    30.03.1981
    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.
    20.06.1981
    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.
    20.06.1983
    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.
    15.02.2006
    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.
    52.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4330.0
    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).
    4330.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.5
    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.
    EARLY 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.
    ROTLIEGEND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 29' 58.37'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 4' 8.36'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6262331.32
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    565809.72
    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.
    220
  • Wellbore history

    General
    Well 3/7-2 was drilled on a structure located across blocks 3/4 (Amoco Group) and 3/7 (Petronord Group. The primary targets were: Tertiary sands found gas bearing in well 2/3-1; Danian/Late Cretaceous limestone (chalk) hydrocarbon bearing in the Ekofisk area and in the Danish well Lulu 1; Middle Jurassic sandstones which were hydrocarbon bearing in well 2/6-2; and Rotliegendes sandstones. The TD was planned into the Carboniferous in order to establish the source potential of this formation.
    Operations and results
    Wildcat well 3/7-2 was spudded with the semi-submersible installation Dyvi Alpha on 30 March and drilled to TD at 4330 m in the Early Permian Rotliegendes Group. A drilling break occurred at 2534 m. Flow check at 2553 m showed a weak flow, which was controlled by raising the mud weight to 1.46 sg. Drilling resumed and was stopped at 2563 m for logging. Three days were necessary to run the electric logs because of continuous slight flow. Deviation problems were experienced in the salt. The deviation reached a maximum of 9 1/2 deg at 3659 m then was reduced to 2 1/2 deg at 4004 m. The well was drilled with a lignosulphonate mud from 2563 m to 3027 m. Below the 9 5/8" casing shoe at 3012 m the mud was displaced to a salt saturated mud.
    The Eocene/Oligocene sands were found missing. Only 8 meters of sand were encountered in the Paleocene. The chalk was tight and water bearing. The Jurassic sandstones were not as developed as prognosed, and they were water bearing. No sandstones were encountered in the Rotliegendes Group, which consisted of an upper shale and a lower volcanic unit. Carboniferous sediments were not penetrated. All the targets above the salt were found water bearing while no reservoir was encountered below 4166 m (base salt, F horizon). Prognosed stratigraphy at base Cretaceous and below was in error. Base Cretaceous was encountered 115 m higher than prognosed, top salt was 209 m higher than prognosed, while base salt (F Horizon) was 150 m deeper than prognosed. The interval velocities were confirmed by the velocity surveys, so the wrong picking was due to a weak base Cretaceous reflector, Jurassic sandstones being too thin to provide good reflectors, and the reflector taken for top salt in fact was an intra-salt reflector corresponding to a thick layer of Potassium salt. Rare and weak fluorescences and cuts in the upper Jurassic Shale were the only shows recorded in the well.
    Five cores were cut, three in the Danian/Late Cretaceous Limestone, one in the Middle Jurassic and one at TD in the Rotliegendes basalt. RFT sampling was performed in the Jurassic at 2909 m. The sample was opened and found to contain 9 l salted water (NaCl 115 g/l), slightly contaminated by the lignosulphonate mud. (The mud salinity was 47 g NaCl /l).
    The well was permanently abandoned on 20 June 1981 as a dry well.
    Testing
    No drill stem test was performed in the well.
  • 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]
    155.00
    4320.00
  • 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
    2570.0
    2572.0
    [m ]
    2
    2575.5
    2588.8
    [m ]
    3
    2602.0
    2604.8
    [m ]
    4
    2911.0
    2919.0
    [m ]
    5
    4310.0
    4319.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    35.1
    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
    1960.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2353.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2395.0
    [m]
    DC
    RRI
    2405.0
    [m]
    DC
    RRI
    2415.0
    [m]
    DC
    RRI
    2435.0
    [m]
    DC
    RRI
    2450.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2470.0
    [m]
    DC
    RRI
    2485.0
    [m]
    DC
    RRI
    2495.0
    [m]
    DC
    RRI
    2505.0
    [m]
    DC
    RRI
    2515.0
    [m]
    DC
    RRI
    2525.0
    [m]
    DC
    RRI
    2535.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2557.5
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2824.0
    [m]
    DC
    RRI
    2836.0
    [m]
    DC
    RRI
    2870.0
    [m]
    DC
    RRI
    2882.0
    [m]
    DC
    RRI
    2904.0
    [m]
    DC
    RRI
    2912.3
    [m]
    C
    RRI
    2916.5
    [m]
    C
    RRI
    2936.5
    [m]
    C
    RRI
  • Oil samples at the Norwegian Offshore Directorate

    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    RFT
    2909.00
    0.00
    WATER
    YES
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.68
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.19
  • 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
    300
    2551
    CBL
    2300
    3012
    FDC CNL GR CAL
    753
    2562
    FDC GR CAL
    148
    772
    HDT
    1732
    2560
    HDT
    2554
    3026
    HDT
    3010
    4293
    ISF SONIC GR
    148
    773
    ISF SONIC GR
    754
    1850
    ISF SONIC GR
    1800
    2562
    ISF SONIC NGT
    2554
    3027
    ISF SONIC NGT
    3010
    4244
    ISF SONIC NGT
    4023
    4324
    LDL CNL GR CAL
    2553
    3026
    LDL CNL GR CAL
    3011
    4243
    LDL CNL GR CAL
    4122
    4301
    NGS
    3010
    4244
    SONIC GR
    3001
    4000
  • 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
    148.0
    36
    148.0
    0.00
    LOT
    SURF.COND.
    20
    754.0
    26
    770.0
    1.48
    LOT
    INTERM.
    13 3/8
    2554.0
    17 1/2
    2563.0
    1.82
    LOT
    INTERM.
    9 5/8
    3012.0
    12 1/4
    3027.0
    2.05
    LOT
    OPEN HOLE
    4330.0
    8 1/2
    4330.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    170
    1.15
    seawater
    350
    1.19
    seawater
    1140
    1.19
    55.0
    waterbased
    2450
    1.40
    33.0
    waterbased
    2805
    1.50
    36.0
    waterbased
    3050
    1.52
    32.0
    waterbased
    3550
    1.65
    65.0
    waterbased
    3930
    1.70
    70.0
    waterbased
  • 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
    0.22