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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2/3-4

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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.
    2/3-4
    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.
    2/3-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8252 - 374 SP. 185
    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.
    Norwegian Gulf Exploration Company AS
    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.
    418-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.
    58
    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,
    28.05.1984
    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.
    24.07.1984
    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.
    24.07.1986
    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.
    18.05.2004
    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.
    38.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    56.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3386.0
    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).
    3386.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    109
    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° 46' 45.61'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 48' 27.89'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6293254.69
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    549360.76
    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.
    129

  • Wellbore history
    General
    Well 2/3-4 was drilled by Gulf Oil Corporation - Norway Branch as a non-obligatory well on behalf of the participants in Production Licence 022. All obligatory work had been previously been done. The well is situated 275 km SSW of Stavanger. Geologically, the location was chosen on the "Ula Trend" on the NE flank of the Central Graben in the southern Norwegian North Sea. The principal objective of the well was to test structural closure of Upper Jurassic Ula Formation sandstone. This formation was believed to exist within 100 m below the nearest representative mappable seismic reflection, the Base Cretaceous Unconformity. The well was also planned to penetrate an Oligocene sand down-dip from a very small gas accumulation defined by a seismic flat spot anomaly, and which was therefore believed to be water wet at the location. The chalk reservoir was not predicted to be hydrocarbon bearing, nor was the well located within its mapped closure.
    Operations and results
    Exploration well 2/3-4 was spudded with the jack-up installation Glomar Moray Firth I on 28 may 1984 and drilled to a total depth of 3386.3 m in Permian (Zechstein) evaporites. The well was drilled with seawater and gel down to 651 m and with Safemul oil based mud from 651 m to TD. Some swelling of the Miocene clay occurred during drilling of the 17 1/2" hole, otherwise no major problems occurred. Well 2/3-4 was the first exploration well for which NPD approved that conventional wire line logs was replaced with a suite of MWD logs.
    The primary objective, Ula Formation sands, was penetrated at 3006 m and was 207 m thick. The porosity of particularly the uppermost 170 m was excellent, generally between 25% and 30%. Electric logs, and a formation fluid sample (from FMT), indicated that the reservoir was water bearing throughout. Shows detection was made difficult due to the mud used. However, spectrofluorometric analyses on cuttings samples while drilling indicated that real shows could be present in the interval between 3045 m and 3006 m. The formation pressure gradient of 1.51 psi/m (0.46 psi/ft) within the reservoir further confirmed that the pore fluid was water, and that no vertical permeability barriers were present. Two segregated FMT samples were taken at 3011.5 m and 3073 m, both contained water. One core was cut from 3125.3 m to 3144.3 m in the Ula Formation sandstone. An anomalous high gamma ray peak was observed at 3030.6 m. The well was permanently abandoned as a dry well on 24 July 1984.
    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]
    200.00
    3386.00

  • 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
    3125.4
    3144.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    18.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3125-3128m
    Core photo at depth: 3129-3132m
    Core photo at depth: 3133-3136m
    Core photo at depth: 3137-3140m
    Core photo at depth: 3141-3143m
    3125-3128m
    3129-3132m
    3133-3136m
    3137-3140m
    3141-3143m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1400.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1905.0
    [m]
    DC
    RRI
    1915.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1945.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1975.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2005.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2035.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2065.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2095.0
    [m]
    DC
    RRI
    2105.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2125.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2155.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2185.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2215.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2245.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2275.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2305.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2335.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2365.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2395.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2425.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2450.0
    [m]
    DC
    RRI
    2455.0
    [m]
    DC
    RRI
    2470.0
    [m]
    DC
    RRI
    2485.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2505.0
    [m]
    DC
    RRI
    2515.0
    [m]
    DC
    RRI
    2525.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2535.0
    [m]
    DC
    RRI
    2545.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2575.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2605.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2620.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    RRI
    2675.0
    [m]
    DC
    RRI
    2680.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    RRI
    2695.0
    [m]
    DC
    RRI
    2710.0
    [m]
    DC
    RRI
    2785.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    RRI
    3000.0
    [m]
    DC
    RRI
    3006.0
    [m]
    DC
    RRI
    3034.0
    [m]
    DC
    RRI
    3060.0
    [m]
    DC
    RRI
    3113.0
    [m]
    DC
    RRI
    3135.5
    [m]
    DC
    RRI
    3142.0
    [m]
    DC
    RRI
    3144.0
    [m]
    DC
    RRI
    3180.0
    [m]
    DC
    RRI
    3188.0
    [m]
    DC
    RRI
    3204.0
    [m]
    DC
    RRI
    3236.0
    [m]
    DC
    RRI
    3248.0
    [m]
    DC
    RRI
    3256.0
    [m]
    DC
    RRI
    3268.0
    [m]
    DC
    RRI
    3302.0
    [m]
    DC
    RRI
    3322.0
    [m]
    DC
    RRI
    3334.0
    [m]
    DC
    RRI
    3342.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.52

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.40

  • 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
    1.98
    pdf
    23.56

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DIFL ACL CDL CN GR CAL
    1685
    2965
    DIFL ACL CDL CN GR CAL
    2959
    3139
    DIFL ACL CDL CN GR CAL
    3060
    3381
    DIFL ACL CDL GR CAL
    611
    1764
    DIPLOG
    2959
    3382
    FMT
    0
    0
    MWD - GR
    644
    1780
    MWD - GR
    1828
    2959
    MWD - GR RES
    195
    644
    TEMP
    20
    620
    TEMP
    500
    2940
    VELOCITY
    611
    3381
    VSP
    1600
    3370
    XY CAL GR
    157
    648

  • 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
    183.5
    36
    335.3
    0.00
    LOT
    SURF.COND.
    20
    644.5
    26
    650.5
    1.49
    LOT
    INTERM.
    13 3/8
    1770.6
    17 1/2
    1786.0
    1.74
    LOT
    INTERM.
    9 5/8
    2963.9
    12 1/4
    2967.8
    1.92
    LOT
    OPEN HOLE
    3386.0
    8 1/2
    3386.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    128
    1.43
    WATER BASED
    29.05.1984
    201
    1.32
    WATER BASED
    31.05.1984
    201
    1.32
    WATER BASED
    31.05.1984
    201
    1.04
    WATER BASED
    04.06.1984
    639
    1.14
    330.0
    200.0
    OIL BASED
    15.06.1984
    651
    1.05
    6.0
    29.0
    WATER BASED
    05.06.1984
    1213
    1.26
    31.0
    22.0
    OIL BASED
    17.06.1984
    1771
    1.38
    37.0
    25.0
    OIL BASED
    25.06.1984
    2157
    1.40
    32.0
    25.0
    OIL BASED
    28.06.1984
    2563
    1.41
    39.0
    27.0
    OIL BASED
    02.07.1984
    2795
    1.41
    34.0
    11.1
    OIL BASED
    04.07.1984
    2889
    1.41
    32.0
    10.6
    OIL BASED
    04.07.1984
    2968
    1.49
    35.0
    15.4
    OIL BASED
    06.07.1984
    3001
    1.53
    36.0
    14.9
    OIL BASED
    11.07.1984
    3125
    1.56
    36.0
    14.9
    OIL BASED
    13.07.1984

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3136.00
    [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
    0.23