Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

25/2-4

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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.
    25/2-4
    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
    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.
    25/2-4
    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 Petroleum Norge 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.
    129-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.
    160
    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,
    14.05.1975
    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.
    20.10.1975
    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.
    20.10.1977
    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.
    29.06.2004
    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
    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.
    GAS/CONDENSATE
    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.
    MIDDLE JURASSIC
    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.
    HUGIN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    113.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4360.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    144
    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 TRIASSIC
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 58' 44.09'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 22' 58.88'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6649378.84
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    465563.12
    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.
    356

  • Wellbore history
    General
    Well 25/2-4 was drilled in the north west corner of block 25/2. It lies on the eastern flank of the Viking basin in the Viking Graben and to the east of the Frigg Field and Frigg Kitchen. The main targets was the Jurassic with a mapped seismic structure of 30 ms vertical closure and 30 square km acreage spreading on the Shell block 30/11. Well 25/2-4 was located on the west flank near the top of the structure. Agreement with Shell management was signed for a bottom hole contribution with obligation for the operator to reach the Triassic red shales or to set TD at 3360 m.
    The well is Reference Well for the Drake Formation.
    Operations and results
    Exploration well 25/2-4 was spudded with the semi-submersible installation Neptune 7 on 14 may 1975 and drilled to TD at 4384 m in the Triassic Smith Bank Formation. The well was drilled water based with salt/gel/Flosal/seawater down to 733 m and with FCL/LC mud from 733 m to TD. At 3375 m the well kicked due to an under balanced hydrostatic mud pressure.
    The well penetrated Danian, Paleocene and Eoceneá sandstone sequences (Frigg Formation, Intra Balder Formation Sandstones, Hermod and Ty formations). All these sands were water wet without shows. In the Late Cretaceous limestones were found fairly well developed overlying a thick shaly and marly sequence with some more limestone levels, particularly in the Campanian and Turonian. The latter limestones contained significant shows, but a production test proved tight formation. The Kimmerian unconformity was penetrated at 3632 m with 8 m Draupne shale. In the Jurassic two reservoir sandstone sequences were encountered: the Vestland Group and the Statfjord Formation. The Vestland sequence was first interpreted as oil and gas bearing from 3640 m to 3708 m (Hugin Formation) with a probable gas/oil contact 3660 m and an oil/water contact between 3704 m to 3708 m. Net pay in the 25/2-4 Hugin reservoir was estimated around 40 m with porosity from logs averaging 25% and water saturation lower than 25%. The Statfjord sandstones had similar reservoir properties, but were water wet. Due to high pressure the hydrocarbon zone in Hugin Formation was not production tested, in stead fifteen FIT samples were taken, of which five were taken in the "gas zone" and 11 in the "oil zone". Four of the tests were unsuccessful, the remaining samples recovered oil and gas but PVT analyses indicated that the fluids were not fully representative of the formation fluid. After a well test in a later well, 25/2-12 A, it became clear that the reservoir fluid was actually gas with high condensate content. Logs in 25/2-12 confirmed the hydrocarbon/water contact found in 25/2-4 (3678m MSL).
    Shows were recorded as follows: At 2750 m gas index and formation pressure increased significantly and remained high down to 3710 m. Peaks of gas were recorded when entering limestone stringers throughout the Late Cretaceous and at the top of the Jurassic sandstones. Direct fluorescence and cuts were observed over the interval 2900 m to 3877 m on limestones and sandstones.
    Three cores were cut in the Hugin Formation and three in the Sleipner Formation, 81.75 m in total. In addition to the FIT samples in the Hugin Formation one FIT was taken in the Tryggvason Formation (3374 m: mud filtrate and trace gas) and one in the Statfjord Formation (4116 m: mud filtrate only).
    Testing
    Campanian limestones were tested over the interval 2902m to 2913 m. No significant flow was recorded even after acid treatment. Only 3.2 m of mud mixed with water and gas were recovered by reverse circulation. No production test was conducted on the Jurassic oil column because rig equipment was inadequate for the reservoir pressures encountered.

  • 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]
    210.00
    4360.00

  • 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
    3650.0
    3659.0
    [m ]
    2
    3659.0
    3676.0
    [m ]
    3
    3677.0
    3695.0
    [m ]
    4
    3817.0
    3833.8
    [m ]
    5
    3835.0
    3845.0
    [m ]
    6
    3852.0
    3863.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    81.8
    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
    195.0
    36
    200.0
    0.00
    LOT
    INTERM.
    20
    723.0
    26
    733.0
    0.00
    LOT
    INTERM.
    13 3/8
    2860.0
    17 1/2
    2870.0
    0.00
    LOT
    INTERM.
    9 5/8
    3353.0
    12 1/4
    3374.0
    0.00
    LOT
    OPEN HOLE
    4360.0
    8 1/2
    4360.0
    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
    2902
    2911
    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
    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

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC
    724
    3351
    BHC-C
    3351
    4358
    CBL
    2800
    4253
    CBL
    2825
    3350
    CBL
    3020
    3350
    CBL
    3250
    3725
    CBL
    4050
    4138
    CDM
    1950
    4259
    CDM AP
    1950
    4259
    CDM FP
    1951
    4258
    CDM SP
    1950
    4259
    DLL
    3550
    3903
    FDC
    2000
    2100
    FDC
    2550
    2867
    FDC CNL
    3351
    3909
    GR
    137
    724
    IES
    724
    4361
    ML MLL
    2859
    2949
    MLL ML
    3351
    3913
    TEMP
    127
    724
    TEMP
    1580
    2004
    TEMP
    3150
    3500

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.39

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.27

  • 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
    7.82
    pdf
    0.17
    pdf
    15.24
    pdf
    2.45
    pdf
    2.86

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    136
    1.06
    100.0
    water based
    700
    1.05
    100.0
    water based
    1437
    1.18
    60.0
    12.0
    water based
    2147
    1.25
    55.0
    11.0
    water based
    3380
    1.91
    53.0
    18.0
    water based
    3640
    1.92
    60.0
    water based
    3915
    1.93
    54.0
    22.0
    water based
    4260
    1.94
    56.0
    22.0
    water based
    4360
    1.77
    66.0
    water based

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2580.0
    [m]
    DC
    OD
    2600.0
    [m]
    DC
    OD
    2620.0
    [m]
    DC
    OD
    2640.0
    [m]
    DC
    OD
    2660.0
    [m]
    DC
    OD
    2680.0
    [m]
    DC
    OD
    2700.0
    [m]
    DC
    OD
    2720.0
    [m]
    DC
    OD
    2740.0
    [m]
    DC
    OD
    2760.0
    [m]
    DC
    OD
    2780.0
    [m]
    DC
    OD
    2800.0
    [m]
    DC
    OD
    2820.0
    [m]
    DC
    OD
    2840.0
    [m]
    DC
    OD
    2860.0
    [m]
    DC
    OD
    2880.0
    [m]
    DC
    OD
    2900.0
    [m]
    DC
    OD
    2920.0
    [m]
    DC
    OD
    2940.0
    [m]
    DC
    OD
    2960.0
    [m]
    DC
    OD
    2980.0
    [m]
    DC
    OD
    3020.0
    [m]
    DC
    OD
    3040.0
    [m]
    DC
    OD
    3060.0
    [m]
    DC
    OD
    3080.0
    [m]
    DC
    OD
    3100.0
    [m]
    DC
    OD
    3120.0
    [m]
    DC
    OD
    3140.0
    [m]
    DC
    OD
    3160.0
    [m]
    DC
    OD
    3180.0
    [m]
    DC
    OD
    3200.0
    [m]
    DC
    OD
    3220.0
    [m]
    DC
    OD
    3235.0
    [m]
    DC
    OD
    3255.0
    [m]
    DC
    OD
    3275.0
    [m]
    DC
    OD
    3295.0
    [m]
    DC
    OD
    3315.0
    [m]
    DC
    OD
    3335.0
    [m]
    DC
    OD
    3355.0
    [m]
    DC
    OD
    3380.0
    [m]
    DC
    OD
    3400.0
    [m]
    DC
    OD
    3420.0
    [m]
    DC
    OD
    3440.0
    [m]
    DC
    OD
    3460.0
    [m]
    DC
    OD
    3485.0
    [m]
    DC
    OD
    3500.0
    [m]
    DC
    OD
    3520.0
    [m]
    DC
    OD
    3540.0
    [m]
    DC
    OD
    3560.0
    [m]
    DC
    OD
    3585.0
    [m]
    DC
    OD
    3600.0
    [m]
    DC
    OD
    3620.0
    [m]
    DC
    OD